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HELICOPTER OPERATIONS - This Sikorsky S55 is one of the Commission's fleet of seven 
helicopters used in surveying, in maintaining transmission lines and spraying rights of 
way for the control of wood growth, and for transporting men and equipment to remote 
or inaccessible areas. 



The further use of the Sikorsky S55 for sky-wire stringing and for transporting aluminum 
transmission towers to line locations is now proposed. 




The Hydro-Electric Power Commission of Ontario 



Fifty -third 

Annual Report 

for the Year 

I960 kl 



This Report is published pursuant to The Power Commission Act, 
Revised Statutes of Ontario, 1960, Chapter 300, Section 10. 



620 University Ave. 



Toronto, Canada 



MAY 17 1Jft3 

* fglTY OF TO^t 

84i*4ft 



THE HYDRO-ELECTRIC POWER COMMISSION OF ONTARIO 

December 1960 



James S. Duncan, c.m.g., ll.d. 
Chairman 



W. Ross Strike, q.c. 
1st Vice- Chairman 



Hon. Robert W. Macaulay, q.c, m.l.a. 

2nd Vice- Chairman 



Lt.-Col. A. A. Kennedy, d.s.o., e.d. 
Commissioner 



D. P. Cliff 

Commissioner 



Ernest B. Easson 
Secretary 



J. M. Hambley 
General Manager 



H. A. Smith 

Assistant General Manager 
Engineering 



E. H. Banks 

Assistant General Manager 
Finance 



I. K. SlTZER 

Assistant General Manager 
Production and Marketing 



C. B. C. Scott 

Assistant General Manager 

Personnel 



H. J. Sissons 

Assistant General Manager 

Services 



LETTER OF TRANSMITTAL 



Toronto, Ontario, May 23, 1961 

The Honourable John Keiller Mackay, d.s.o., v.d., ll.d. 
Lieutenant-Governor of Ontario 

Sir: 

I have the honour to present the Annual Report of The Hydro- Electric 
Power Commission of Ontario for the year ended December 31, 1960. 

The achievements of 1960 must be assessed in the light of the tensions 
and uncertainties that clouded the international scene, and in relation to the 
many evidences of economic dislocation in our own Canadian affairs. The 
slackening in the rate of national economic progress and the restrictive influence 
of rising unemployment were reflected in the Commission's operations, and to 
the extent that they were reflected, the latter part of 1960 failed to justify the 
promise given in the early months of the year. 

iv 



Power requirements reached a new peak of 5,745,700 kilowatts, 3.4 pei 

above the peak for 1959. It is true that this increase hardly bears comparison 
with the best in the past ten years, and that it falls well short of the long-term 
rate of growth of 6.6 per cent per annum: in fact it is the lowest annual increase 
since 1949. 

In the light of the mild recession we have been experiencing, the results for 
1960 are no occasion for anxiety. Indeed, there is cause for some satisfaction in 
the fact that in a year of so-called rolling economic adjustment we sent out over 
our transmission networks a total of 37.7 billion kilowatt-hours of electric 
energy, generated and purchased. 6.3 per cent more than in 1959. 

The capacity of the power resources available to meet December peak 
loads was 6.526,150 kilowatts. The capacity available to the combined net- 
works of the Southern Ontario System and the Northeastern Division of the 
Northern Ontario Properties left a margin of reserve of under 12 per cent to 
meet load growth and unforeseen contingencies. The margin would have been 
much smaller had there not been a marked decline in the uranium mining 
industry. In the Northwestern Division the termination of a large dredging 
operation and a slackening in the rate of industrial growth, particularly in the 
pulp and paper industry, brought loads considerably below the forecast levels 
on which the Commission's power development program was based. The fore- 
casts reflected estimates of power requirements made by the Commission's 
customers, which, in the light of subsequent events, proved too optimistic. 
Reserves of power in this Division are therefore greater than normally required. 
There are evidences, however, that this is a temporary situation, and that the 
next few years will see new industrial developments in this area bringing loads 
back to the long-term trend of growth. 

The Commission's net primary revenue for the year amounted to S229.2 
million as compared with S212.6 million in 1959, an increase of 7.8 per cent. 
The cost of providing service to the cost-contract municipal utilities was 
SI. 765. 391 less than the amount billed at interim rates and this net amount was 
returned to the utilities in year-end adjustments. 

The Commission has striven continuously over the years to stem the tide 
of inflationary pressures. Like other business enterprises, however, it has been 
confronted with increased interest rates, rising costs of labour and materials, 
and higher taxation, the cumulative effects of which must ultimately be trans- 
lated into increased rates for power. In 1960, higher interim rates were intro- 
duced for the majority of the municipal utilities, rates were increased for certain 
direct industrial customers served by the Southern Ontario System, and towards 
the end of the year a general increase was levied for service to direct industrial 
customers in the Northern Ontario Properties. This general increase was the 
first in nearly eight years, and the resulting increase in revenue in 1960 was 
barely sufficient to meet the rising costs of service to these customers. The cost 
of service to certain cost-contract municipal utilities in the Northern Ontario 
Properties formerly served by the Thunder Bay System was substantially 
greater than the revenues they provided, and it was again necessary to make 
withdrawals from the reserve for stabilization of rates and contingencies held 
specifically for their benefit. 



Expenditures on new facilities were kept at the lowest level since 1955, 
which, together with other measures taken to conserve working capital, enabled 
the Commission to reduce its borrowings from $125 million in 1959 to $100 
million in 1960. In view of the continuing high interest rates, every effort will 
be made to restrict borrowings in 1961 to the same or even lower levels. During 
1960, economies were achieved through the reduction of inventories and through 
improved efficiency in various segments of the Commission's operations. 

The investment in fixed assets at cost rose from $2,248 million to $2,361 
million. Approximately 60 per cent of the capital expenditure during 1960 
was for generating facilities. These include the new thermal-electric stations 
at Lakeview and Thunder Bay, major additions to the Richard L. Hearn 
Generating Station, the Nuclear Power Demonstration plant due to go into 
service in 1961, and developmental and initial construction work for the Douglas 
Point Nuclear Power Station. They also include five hydraulic projects in 
northern Ontario which form part of the program for developing approximately 
2 million kilowatts of hydro-electric power over a period of several years. One 
of these five projects, Red Rock Falls Generating Station on the Mississagi 
River, is now in service, the first of two 20,000-kilowatt units being placed in 
service in November 1960 and the second in January 1961. The others are 
Otter Rapids Generating Station on the Abitibi River, and Little Long, Harmon, 
and Kipling Generating Stations on the Mattagami River. Later this year, 
construction will begin on the first major 460-kv transmission line in North 
America, which will bring power ultimately at this voltage from these last four 
stations in the James Bay watershed to load centres in southern Ontario. 

For more than half a century the customers served by this Commission and 
its associated utilities have been world leaders in the use of many types of 
household appliances, and in the quantity of electric energy consumed. There is 
a wide diversity in the daily use of these appliances, and since the cost of electri- 
city supplied at the retail level does not increase in proportion to the customer's 
use, this high energy consumption has been a major factor in making possible 
the Commission's unusually favourable rates. The maintenance of these 
favourable rates is dependent, however, on a continuing high level of consump- 
tion of electricity per customer. 

This end must be achieved today under greatly changed competitive 
conditions. During the past ten years the. Commission's major problem was 
to provide sufficient power capacity to meet the requirements of the homes, 
farms, and industries in Ontario. Today the Commission, in common with 
the electrical industry in general, faces keen competition from many other 
commodities and services attractive to the customer, and the Commission, in 
particular, must compete with natural gas being offered at highly promotional 
rates. For this reason the Commission, in co-operation with the municipal 
utilities and the entire electrical industry, has embarked on a comprehensive 
program to make its customers increasingly aware of the advantages and 
economies to be derived from using the wide range of new and improved electrical 
appliances and equipment being produced by manufacturers. 

vi 



The Commission's rural distribution facilities, at the end of 1960, were 
serving 499,291 customers over 47,896 miles of primary distribution line. These 
facilities make the benefits of electrical living available to more than 95 per cent 
of all the farms in Ontario. Over ten thousand farms in northern Ontario are 
now being supplied with electric power. Considering the nature and extent 
of the area served and the sparsity of the population, the Commission's record 
of rural service is unsurpassed anywhere in the world. 

Evidences of returning confidence in certain sections of the business com- 
munity give rise to hopes for a modest upturn in the economy before the end 
of 1961. The Commission, with its construction program of necessity already 
under way to meet power requirements for several years ahead, is making a 
significant contribution to this business recovery. 

May I pay a sincere tribute to the members of the staff for their continued 
loyalty. Their skilful, energetic, and conscientious effort in serving the Com- 
mission is indeed a worthy contribution to the Province as a whole. To the 
executive officers of the organization and also to my fellow Commissioners I 
express my sincere thanks for the assistance they always so generously provide. 

Respectfully submitted, 



JAMES S. DUNCAN, 

Chairman. 



CONTENTS 

Letter of Transmittal ____---_ j v 

List of Illustrations .....--- x 

List of Diagrams --------- xii 

Section Page 

Foreword _.._------ l 

Guide to the Report -------- 7 

I Operation of the Systems ------- 9 

Southern Ontario System - - - - - - - 13 

Northern Ontario Properties - - - - - - 15 

Maintenance of the Systems ------- 16 

II Finance ---------- 20 

Combined Systems — 1960 - - - - - - - 21 

Operating Results by SystExMS — 1960 ------ 25 

Balance Sheet — Southern Ontario System - - - - 28 

Balance Sheet — Northern Ontario Properties - 30 

Statement of Operations — Southern Ontario System 32 

Statement of Operations — Northern Ontario Properties - - 33 

Statement of Funded Debt ------- 34 

Statement of Advances from the Province of Ontario - - 36 



III The Commission's Customers -------- 38 

Municipal Electrical Utilities and Local Systems - 41 

Direct Industrial Customers and Interconnected Systems - - 42 

Rural Electrical Service ------- 45 

Reports from the Regions ------- 49 

Public Relations and Services to Customers - 57 

IV Planning, Engineering, and Construction ----- 59 

Southern Ontario System 

Progress on Power Developments ----- 63 

Transformer Stations ------- 66 

Transmission Lines -------- 68 

Northern Ontario Properties 

Progress on Power Developments ----- 69 

Transformer Stations and Transmission Lines 77 



Contents ix 

Section Page 

V Research and Testing Activities ..._.. 79 

VI Staff Relations ----------86 

Appendix 

I Operations _..---.--- 91 

The Commission's Power Resources ------ 92 

Resources and Loads -------- 94 

Analysis of Energy Sales ------- 96 



II Financial ---------- 99 

Southern Ontario System 

Schedules Supporting the Balance Sheet - 100 

Allocation of the Cost of Primary Power - - - 108 

Sinking Fund Equity ------- 128 

Northern Ontario Properties 

Schedules Supporting the Balance Sheet - 136 

Allocation of the Cost of Primary Power - 142 

Sinking Fund Equity -------- 146 

III Rural - 147 

Description of Main Classes of Service ----- 147 

Rates and Typical Bills for Service to Rural Customers - - 148 

Miles of Line and Number of Customers by Rural Operating Areas - 151 

Customers, Revenue, and Consumption 1951-1960 ... - 155 

IV Legislative - - - - - - - - - - 156 

The Power Commission Amendment Act, 1960 - - 156 

Order in Council -------- 161 

Supplement 

Municipal Electrical Service, - - - - - - - 163 

Financial Statements of the Municipal Electrical Utilities - 172 

Rates and Typical Bills for Retail Service - 222 

Customers, Revenue, and Consumption - - - - 244 

List of Abbreviations ---------- 266 

Index - - - - - - ' - . . - - - 266 



ILLUSTRATIONS 



The Commission's Sikorsky S55 Helicopter - .... Frontispiece 



Section Page 
Foreword 

Red Rock Falls Generating Station — Aerial View ... 2 

Lakeview Generating Station — The Powerhouse Structure - - 4 

Thunder Bay Generating Station ------ 5 

Otter Rapids Generating Station — Part of the Headworks Structure 6 



Operation of the Systems 

Richard L. Hearn Generating Station 

Units Number 5 and 6 - - - - - - - 11 

Load Rejection Tests - - - - - - - 13 

On-site Repairs to a Large Transformer - - - - - 16 

Air-blast Circuit-breaker at Burlington Transformer Station - 17 

Rehabilitation of Tower Footings - - - - - - 18 

Wind-speed and Wind-direction Indicator - - - - - 19 



1 1 Finance 

Douglas Point Nuclear Power Station 

The Station Site, December 1960 ..... 22 

Scale Model of the Station ------ 25 

Lakeview Generating Station — Aerial View - 26 



III The Commission's Customers 

Appliance Demonstration Centre of the London 

Public Utilities Commission - ----- 39 

Digital Demand Recorder Used in Residential Survey - - 40 

Home Economists in Training at the University of Toronto - - 41 

Machining Operation at a Large Electrical Manufacturing Plant 45 

Bulk Milk Cooler in a Dairy Farm Installation 48 

Barn-cleaning Machinery ------- 49 

Essex Rural Area Office -------- 50 

Stratford Public Utility Commission Office - - - - 51 

Lakeview Generating Station 

The Steam Drum ... .... 53 

The Super-heater Outlet Header ----- 53 

\uclear Power Demonstration — Inside Well Wall of the Reactor - 55 

Thunder Bay Generating Station— Installation of the Generator 56 



Illustrations xi 

Section Page 

IV Planning, Engineering, and Construction 

The Site of Little Long Generating Station - 60 

Otter Rapids Generating Station 

June 1960 - - 61 

Constructing the Earth Wing-dams ----- 70 

Tree Crusher at Work -------- 71 

Bailey Bridge at Little Long Generating Station - 71 

Red Rock Falls Generating Station 

Progress of Construction, October 1960 ----- 73 

The Log-chute - - - - - - - - 74 

The Generator Room -------- 75 

Stator Being Installed ------- 76 

Helicopter Crew Taking a Reading on a Surveying Altimeter - - 77 

Model of a Guyed Aluminum Transmission Tower ... 77 



Research and Testing Activities 

Using Live-line Tools on a 460-kv Test Line ----- 80 

Live-line Vibration Recorder ------ 81 

Measuring Shear Strengths of Clays ------ 82 

Closed-circuit Television Camera Used in Inaccessible Locations - 83 

Measuring the Load-carrying Capacity of Ice Cover 84 



VI Staff Relations 

Little Long Generating Station 

Staff Cottages - - - 87 

Commission-operated Store ------- 88 



DIAGRAMS 



Section 



Foreword 

Total Power Resources and Energy Production 



Page 



Operation of the Systems 

Power Demands and Resources 
Southern Ontario System 



12 



Northern Ontario Properties 
Northeastern Division 
Northwestern Division 



1-1 

15 



II Finance 

Fixed Assets, Capital, and Long-term Liabilities 



23 



III The Commission's Customers 

Primary Power and Energy Delivered to 

Municipal Electrical Utilities and Local Systems 
Direct Industrial Customers - 

Rural Power District - 
Rural Service — Miles of Line and Number of Customers 



42 
43 
46 

47 



Appendix 
III Rural 

Sketch Map of Rural Operating Areas 



facing page 148 



Supplement 

Municipal Electrical Service 

Annual Energy Consumption and Average Cost per Kilowatt-hour 165 

Municipal Electrical Utilities 

Revenue ---------- 166 

Fixed Assets and Long-term Debt ----- 167 



FIFTY-THIRD ANNUAL REPORT 

OF 

The Hydro'Electric Power Commission 

of Ontario 



FOREWORD 

v I ^HE Hydro-Electric Power Commission of Ontario is a corporate entity, 
■*■ a self-sustaining public enterprise endowed with broad powers with respect 
to electricity supply throughout the Province of Ontario. Its authority is 
derived from an Act of the Provincial Legislature passed in 1906 to give effect 
to recommendations of earlier advisory commissions that the water powers of 
Ontario should be conserved and developed for the benefit of the people of the 
Province. It now operates under The Power Commission Act (7-Edward VII, 
c. 19) passed in 1907 as an amplification of the Act of 1906 and subsequently 
modified from time to time (Revised Statutes of Ontario, 1960, c. 300). The 
Commission may have from three to six members, all of whom are appointed by 
the Lieutenant-Governor in Council. One commissioner must, and a second 
commissioner may, be a member of the Executive Council of the Province of 
Ontario. 



Foreword 



Systems and the Power Supply 

For the financial and administrative purposes of the Commission, the 
Province is divided into two parts. The roughly triangular part lying south 
of Lake Nipissing and the French and Mattawa Rivers is served by the Southern 
Ontario System, a fully integrated power system combining the Niagara, Georgian 
Bay, and Eastern Ontario Divisions. The system is operated on a co-operative 
basis predominantly for the benefit of more than three hundred municipal 
electrical utilities supplied with power at cost, but in part also for the benefit 
of the Rural Power District which it serves. The northern part of the Province 
is served by the Northern Ontario Properties, held and operated for the most 
part in trust for the Province, but operated in part also for the benefit of a group 
of utilities supplied with power at cost. The Northern Ontario Properties 
include a Northeastern and a Northwestern Division. Each of these two divisions 
is an integrated power system, the former being interconnected with the Southern 
Ontario System. 

In addition to administering the enterprise over which it has direct control, 
the Commission exercises certain regulatory functions with respect to the group 
of municipal electrical utilities which it serves. In order to provide convenient 
and expeditious service in this dual function of regulation and supply, the Com- 
mission has subdivided its province-wide operations into nine regions, seven 
in the south and two in the north, with regional offices located in nine major 
municipalities. At present the two northern regions coincide with the two 
northern divisions. 

The Commission is primarily concerned with the provision of electric 
power by generation or purchase and its delivery in bulk either for resale, or for 
use in the industrial operations of certain customers served directly. Power 




RED ROCK FALLS GENERATING STATION — The 952-foot power dam spans the Mississagi River at a point 
1 5 miles down stream from George W. Rayner Generating Station. 



Power Resources and Energy Production 



THE HYDRO-ELECTRIC POWER COMMISSION OF ONTARIO 



TOTAL POWER RESOURCES AND ENERGY PRODUCTION 



MILLION KILOWATTS 



DECEMBER DEPENDABLE PEAK CAPACITY 



of power purchased 



of Commission generating stations 



1950 



T 

1955 



1960 



BILLION KILOWATT-HOURS 



ANNUAL ENERGY PRODUCTION 



Purchased 



Generated 



T 

1940 



T 

1345 



T 

1950 



T 

1955 



Foreword 




LAKEVIEW GENERATING STATION — The powerhouse structure, equivalent in height to a 20-storey building, 

and the 493-foot chimney are framed in part of the switchyard structure. The first of the four 300,000-kilowatt 

units to be installed at the station will be placed in service in 1961. 



for resale is delivered to the associated municipal electrical utilities, and to 
certain interconnected systems, including a number of independent municipal 
distribution systems, operating within or beyond the Provincial boundaries. 
The industrial customers served directly include mines and industries in un- 
organized areas. Some power users located within areas served by the municipal 
utilities are also served by the Commission since their power requirements may 
be so large or may create supply conditions so unusual as to make service by the 
local municipal utilities impracticable. In total, bulk delivery for resale and 
for industrial use accounts for about 90 per cent of the Commission's energy 
sales. The remaining 10 per cent of the Commission's sales are made to ultimate 
customers either in rural areas served on behalf of the townships by the Com- 
mission's rural distribution facilities, or in a relatively small group of municipalities 
served by Commission-owned local distribution systems. In general, however, 
retail service to ultimate customers in most cities and towns, in many villages, 
and in certain populous township areas is supplied by the associated electrical 
utilities, owned and operated by local commissions and functioning under the 
general supervision of The Hydro-Electric Power Commission of Ontario as 
provided for in The Power Commission Act and The Public Utilities Act. 

Financial Features 

The basic principle governing financial operations of the undertaking and 
its associated municipal electrical utilities is that service is provided at cost. 
In the Commission's operations, cost of service includes payment for power 



Annual Summary — 1960 5 

purchased, charges for operating and maintaining the power systems, and 
related fixed charges. The fixed charges represent interest on debt, reserve 
provisions for depreciation and for contingencies and rate stabilization, and the 
further provision of a sinking fund reserve for retiring the Commission's long-term 
debt. The municipal utilities operating under cost contracts with the Commis- 
sion are billed throughout the year at interim rates based on estimates of the 
cost of service. At the end of the year, when the actual cost of service is 
established, the necessary balancing (debit or credit) adjustments are made 
in their accounts. Retail rates for the municipal utilities are established at 
levels calculated to produce adequate revenue to meet cost. The Commission's 
retail rate structure for rural service other than industrial power service has been 
uniform throughout the Province since 1944. 

The enterprise from its inception has been self-sustaining. The Province, 
however, guarantees the payment of principal and interest on all bonds issued 
by the Commission and held by the public. In addition, the Province has 
materially assisted the development of agriculture by contributing under The 
Rural Hydro-Electric Distribution Act toward the capital cost of extending 
rural distribution facilities. 

Annual Summary — 1960 

During 1960 the principal construction work was carried out at six locations. 
Two were hydro-electric developments in northern Ontario, Red Rock Falls on 
the Mississagi River and Otter Rapids on the Abitibi River. The others were 
Lakeview and Richard L. Hearn Generating Stations in the Toronto area, 
Thunder Bay Generating Station in Fort William, and the Nuclear Power 










THUNDER BAY GENERATING STATION — Against a background of the ice-bound waters of Thunder Bay, the 
almost completed 1 00,000-kilowatt thermal-electric station is a striking landmark on the north shore of the 

Mission River in Fort William. 



Foreword 



Statistical 



195 



Dependable peak capacity, December thousand kw 2,942 

Primary power requirements, December thousand kw 3,109 

Annual energy generated and purchased million kwh 18,811 

Primary million kwh 1 7,544 

Secondary million kwh 1,267 

Annual energy sold by the Commission million kwh 16,632 

Annual revenue of the Commission (net after refunds) million $ 102 

Fixed assets at cost million $ 1 ,020 

Gross expenditure on fixed assets in year million $ 165 

Total assets, less accumulated depreciation million $ 1,099 

Long-term debt million $ 690 

Transmission line circuit miles 14,280 

Primary rural distribution line circuit miles 38,198 

Average number of employees in year 21,174 

Number of associated municipal electrical utilities 324 

Ultimate customers served by the Commission and municipal utilities thousands 1,249 



Demonstration plant near Chalk River on the Ottawa River. Four other 
projects added to the capital construction program during the year were the 
Douglas Point Nuclear Power Station near Kincardine and three hydraulic 
developments on the Mattagami River in the James Bay watershed to be known 
as Little Long, Harmon, and Kipling Generating Stations. 




OTTER RAPIDS GENERATING STATION — In April 1960 the upstream cofferdam in the western channel was 
breached, permitting the river to flow through the completed diversion ports as well as down the eastern 
channel. The formwork for the transition section and part of the headworks shown was constructed on the 

island separating the two channels. 



Guide to the Report 
Summary 1951-1960 



1952 


1953 


1954 


1955 


1956 


1957 


1958 


1959 


1960 


3,353 


3,565 


4,135 


4,530 


4,552 


4,844 


5,761 


6,155 


6,526 


3,278 


3,488 


3,702 


4,229 


4,514 


4,784 


5,139 


5,556 


5,746 


19,974 


20,912 


22,386 


26,555 


29,523 


31,101 


31,450 


35,465 


37,709 


18,774 


19,951 


20,788 


23,258 


25,537 


27,405 


28,382 


31,546 


32,717 


1,200 


961 


1,598 


3,297 


3,986 


3,696 


3,068 


3,919 


4,992 


17,728 


18,587 


19,928 


23,909 


26,828 


28,318 


28,633 


32,058 


34,317 


112 


136 


143 


162 


183 


197 


198 


213 


229 


1,177 


1,355 


1,469 


1,573 


1,733 


1,931 


2,108 


2,248 


2,361 


163 


184 


133 


115 


173 


209 


191 


154 


132 


1,266 


1,491 


1,653 


1,788 


2,011 


2,255 


2,423 


2,548 


2,660 


862 


1,040 


1,162 


1,209 


1,392 


1,573 


1,691 


1,786 


1,844 


14,813 


15,251 


15,785 


16,115 


16,489 


16,717 


17,499 


17,713 


17,831 


40,277 


41,589 


42,540 


43,851 


44,492 


45,375 


46,438 


47,351 


47,896 


19,570 


19,242 


18,750 


17,278 


18,075 


19,597 


17,701 


15,866 


15,179 


327 


332 


338 


343 


350 


351 


354 


354 


354 


1,316 


1.390 


1,467 


1,540 


1,612 


1,674 


1,757 


1,830 


1,881 



The first of two units at Red Rock Falls Generating Station was placed in 
service in November 1960, and like Unit No. 6 at Richard L. Hearn Generating 
Station, which was placed in service in January 1960, contributed to the increase 
in dependable peak capacity for the year. Unit No. 7 at Richard L. Hearn 
Generating Station was placed in service but was not considered available at 
the time of the system peak in December. The 20,000-kilowatt Nuclear Power 
Demonstration unit is expected to be in operation during the summer of 1961 
and to run under full power by the end of 1961. Meanwhile a site is being 
developed for Douglas Point Nuclear Power Station, between Kincardine and 
Port Elgin on the shore of Lake Huron. 

Net revenue from sales of primary power and energy rose by 7.8 per cent 
during 1960. Revenue from the sale of secondary energy amounting to $9,191,226 
was applied towards the reduction of the cost of power. Total kilowatt-hour 
sales were 7.0 per cent greater than in 1959. 



GUIDE TO THE REPORT 

Details of the Commission's activities which have been briefly summarized 
in the foregoing paragraphs are given in the six sections and four appendices of 
the Report which follow. Operations, finance, and customer relations are the 
subjects of the first three sections and their related appendices. The narrative 
in Section I dealing with the production, purchase, and delivery of power is 
supplemented in the text by reports of weather conditions, maintenance, com- 
munications, and forestry, all of which are related to operations. Supplementary 
tables are in Appendix I. Section II includes the Commission's balance sheets, 



8 Foreword 

statements of financial operations, and tables showing the funded debt and 
advances from the Province of Ontario. Appendix II includes supporting 
schedules and accounts, in addition to the statements of reserves, sinking fund 
equity, and cost of power. In Section III, consideration is given first to the 
wholesale operation of supplying power to municipal electrical utilities and to 
certain interconnected systems for resale, and second to service to certain 
industrial customers supplied directly by the Commission. The supply of 
power in wholesale quantities to the rural operating areas is then briefly discussed 
under the heading Rural Electrical Service. This commentary is immediately 
followed by a discussion of retail aspects of service to ultimate customers served 
by the Commission in these areas. Supplementary information on rural 
service is to be found in Appendix III. Another subsection of Section III, in 
the form of reports from the regions, deals with certain activities relative to service 
in municipal utilities. Many of these activities have involved participation by, 
or the assistance of, members of the Commission's staff. 

Engineering and construction activities are discussed in the two sections 
that follow. Section IV deals with the planning and construction of facilities for 
the delivery of power. It includes descriptions of the more important construc- 
tion projects and statistics relative to these and other facilities for the generation, 
transformation, and delivery of power. Section V contains reports on the 
progress of some of the investigations being conducted by members of the 
Commission's Research Division. 

Section YI deals with aspects of employee relations, training, and staff 
administration. Appendix IV lists Orders in Council and legislation pertaining 
to the Commission's affairs. 

A large part of the Report is devoted to aspects of retail service to ultimate 
customers, especially that provided by the municipal electrical utilities. The 
commentary on these activities and the statistical tables applicable to them 
are brought together in a supplement to the Report entitled Municipal Electrical 
Service beginning on page 163. The complete municipal service supplement 
includes four statements: (1) Statement "A" — balance sheets, (2) Statement 
"B" — operating statements, (3) Statement "C" — rates, and (4) Statement 
"D" — other statistical information relating to the municipal systems. As the 
service rendered by the Commission-owned local systems is comparable to that 
provided by the municipal utilities, the local systems are included in the statistical 
summaries in the municipal supplement and are also listed in Statements "C" 
and "D". 



SECTION I 



OPERATION OF THE SYSTEMS 



v I ^HE total increase in primary power requirements throughout the Commis- 
-*- sion's systems was relatively small during 1960, reflecting the general 
slackening in the rate of growth of the Canadian economy. Primary peak 
demands, all systems, were 3.4 per cent greater in December 1960 than in 
December 1959. Although by general industrial standards an increase of this 
magnitude might be considered satisfactory, it did fall short by a considerable 
margin of the long-term (1922-1960) rate of increase of 6.6 per cent per year. 

During the period intervening between the annual primary peaks in 
December 1959 and December 1960, two 200,000-kilowatt units at Richard L. 
Hearn Generating Station and one 20,000-kilowatt unit at Red Rock Falls 
Generating Station were placed in service. Unit No. 7, one of the two new units 
at Richard L. Hearn Generating Station, was not available at the time of system 
peak in December. Its exclusion from dependable peak capacity figures was 



10 



Operation of the Systems 



POWER SUPPLY STATISTICS— 1960 

(Figures for 1959 and Per Cent Change in Italic Type) 





Southern 
Ontario 
System 


Northern Ontario 
Properties 






North- 
eastern 
Division 


North- 
western 
Division 


Total 


Resources 










Dependable peak capacity 
— December kw 
kw 


5,558,750 

5,213,700 

6.6% 


371,500 

345,400 

7.6% 


595,900 

595,600 

0.1% 


6,526,150 

6,154,700 

6.0% 


Requirements 










Primary 

Peak — Annual maximum kw 
kw 


4,772,583 
4,578,541 

4.2% 


551,661 

550,067 
0.3% 


433,274 
450,748 
-3.9% 


5,745,682* 
5,556,474* 
3.4% 


Energy — Total annual kwh 
kwh 


26,321,825,289 

25,226,267,417 

4.3% 


3,636,699,913 
3,559,611,260 

2.2% 


2,759,000,194 
2,760,792,799 

-o.i% 


32,717,525,396 

31,546,671,476 

3.7% 


Loads 










Primary and Secondary 

Peak — Annual maximum kw 
kw 


5,031,545 
4,913,941 

2-4% 


552,053 

550,067 

0.4% 


574,328 

554,196 

3.6% 


6,157,534* 
6,018,204* 

2.3% 


Energy — Total annual kwh 
kwh 


30,547,653,589 

28,574,335,017 

6.9% 


3,768,375,431 
3,615,319,810 

4.2% 


3,392,853,908 

3,275,759,457 

3.6% 


37,708,882,928 

35,465,414,284 

6.3% 


Primary Only 

Energy — For use in Ontario 
kwh 
kwh 


25,924,170,889 
24,824,180,417 

4.4% 


3,636,699,913 
3,558,196,571 

2.2% 


2,759,000,194 
2,760,792,799 

-o.i% 


• 

32,319,870,996 

31,143,169,787 

3.8% 


— Total annual kwh 
kwh 


26,321,728,089 
25,226,264,417 

4.3% 


3,636,699,913 
3,559,611,260 

2.2% 


2,759,000,194 

2,760,792,799 

-0.1% 


32,717,428,196 

31,546,668,476 

3.7%o 



*These annual maxima are the arithmetic sums of the three non-coincident system peaks in 
December. In the two northern divisions the annual maximum does not necessarily occur 
in December. 



offset by the availability of Unit No. 5, which had been similarly out of service 
in December 1959. The addition of new generating units, coupled with adjust- 
ments in the calculated dependable peak capacities of other generating stations, 
resulted in an increase in the all-system dependable peak capacity of 371,450 
kilowatts, bringing the total to 6,526,150 kilowatts at the end of 1960. Almost 
the entire increase in capacity was on the interconnected networks of the 
Southern Ontario System and the Northeastern Division where, with the small 
concurrent increase in demands, it resulted in an increase in the combined reserve 
capacity from 8.4 per cent of primary peak demand at the end of 1959 to 11.4 



Loads and Capacity — All Systems 



11 



per cent at the end of 1960. In the Northwestern Division, where loads, particu- 
larly in the industrial sector, failed to grow at the expected rate during 1960, 
the reserve continues to be above normal. 

The net output of all resources during 1960 was 37.7 billion kilowatt-hours. 
Of this amount, 31.5 billion kilowatt-hours were produced by the Commission's 
hydro-electric generating stations and 0.2 billion kilowatt-hours by its thermal- 
electric and diesel-electric stations; the balance was purchased. 

There was little requirement for the generation of thermal-electric energy 
during 1960, owing in part to favourable stream-flows, in part to the level of 
demand and the availability of economical assistance from the Commission's 
sources of purchased power. However, these circumstances cannot be expected 
to continue indefinitely and requirements for thermal-electric energy may increase 
sharply at any time. 

An Operations Research team has been working since 1959 on the complex 
problem of efficiently scheduling the use of all major power resources, both 
thermal and hydraulic. Under the program to be introduced in 1961, the Com- 
mission's Univac II computer will prepare daily loading schedules for all major 
power sources, taking into account hour by hour such diverse factors as thermal 
and hydraulic efficiencies, transmission losses, power purchase commitments, 
and revenue from secondary sales. 




RICHARD L HEARN GENERATING STATION— The fifth and sixth units at Richard L. Hearn Generating Station 
are shown in the foreground. Each has an installed capacity of 200,000 kilowatts. By March 1961, these 
and two further units of similar capacity were in service, bringing the total installed capacity of the station 

to 1,200,000 kilowatts. 



\2 



Operation of the Systems 











THE HYDRO-ELECTRIC POWER COMMISSION OF ONTARIO 

POWER DEMANDS AND RESOURCES 
SOUTHERN ONTARIO SYSTEM 

MILLION KILOWATTS 


DECEMBER DEPENDABLE PEAK CAPACITY 

of power purchased 

of Commission generating stations 






t * 


5 
4 
3 
2 
1 






?' 




— •— DECEMBER PRIMARY PEAK REQUIREMENTS 












- 


.-. 






-Dr 


D 


JR 






_ ~ 


- 


- 


- 


"- " 




1940 


1945 


19 


50 1955 1960 



Stream-flow and Storage Conditions 

On the average, water conditions throughout the Southern Ontario System 
and the Northeastern Division were satisfactory during 1960. The annual mean 
flow of the Ottawa River was sufficiently high to more than compensate for the 
below-normal flows of the Niagara and St. Lawrence Rivers. In the spring, 
severe flooding occurred, particularly on the Ottawa and Severn Rivers, as the 
result of heavy rainfall and rapidly melting snow. The flow of the Ottawa 
River at Chats Falls reached a new daily record of 205,000 cfs in May, exceeding 
by 10,000 cfs a previous record set in 1951. Generally high rates of flow con- 
tinued until the middle of July, but during the late summer and fall, precipitation 
was below normal and water in storage decreased to less than normal. In the 
Northeastern Division, stream-flow and water-storage conditions were in general 
above normal throughout the year. Extensive flooding occurred on the Matta- 
gami, Montreal, and Sturgeon Rivers. In the Northwestern Division, water 
conditions were generally below normal during 1960. 



Operations — Southern Ontario System 



13 



SOUTHERN ONTARIO SYSTEM 

In the Southern Ontario System the primary peak demand occurred on 
December 12 and amounted to 4,772,583 kilowatts. The relatively small size 
of the increase in peak demand over the 1959 peak, 4.2 per cent as compared 
with the long-term rate of 6.1 per cent per annum, is attributed to the decline in 
construction and industrial activity throughout the area served during 1960. 

No new hydro-electric generating units were brought into service in the 
Southern Ontario System during 1960. At Richard L. Hearn Generating Station 
in Toronto, Unit No. 7 was taken out of service in November following the 
discovery of damage to the turbine blading. With the good waterflow and 
storage conditions which prevailed during the year, however, it was possible during 
1960 to increase the generation of hydro-electric energy by 7.7 per cent, and 
at the same time reduce the generation of the relatively more costly thermal- 
electric energy by 51 per cent from 1959 levels. Production of energy for 
secondary load purposes during 1960 was 26 per cent greater than during 1959. 

The 25-cycle system of the Niagara Mohawk Power Corporation and the 
Commission's 25-cycle system in the Niagara Falls area were placed in parallel 
operation on April 1, 1960. The parallel operation of the two networks permits 
greater flexibility in the export of power, improves service security, and produces 
operating economies. The use at Sir Adam Beck-Niagara Generating Station 
No. 1 of the frequency-changer formerly installed at Chats Falls Generating 
Station facilitates the interchange of power between the residual 25-cycle network 
and the 60-cycle system. 




LOAD REJECTION TESTS AT RICHARD L. HEARN GENERATING STATION— As part of the Commission's 
acceptance testing procedure, the operation of Unit No. 5 and its auxiliaries is studied under the severe 
conditions imposed by loss of load while the unit is generating maximum power. 

Recording devices and ancillary equipment will record approximately 40 variables, including electrical 
quantities, rotor speeds, steam pressures, temperatures, and the operating times of numerous controls. 



14 



Operation of the Systems 



Early in 1960 a series of tests was made at the Sir Adam Beck-Niagara 
Generating Stations to determine the combined maximum power output of the 
two main stations and the Pumping-Generating Station. Tests were made 
with various initial reservoir elevations. The tests established that, beginning 
with a full reservoir, the stations could achieve a 20-minute peak output of 
1,925,000 kilowatts in approximately one hour under simulated December 
dependable river-flow. The effect of the higher station forebay level associated 
with this method of operation inevitably involves some reduction in energy 
output. On the other hand, the gain in power output will be of greater value, 
particularly when the system peak demand can be satisfied only by this mode of 
operation. 

An extensive description of maintenance activities following the severe 
ice storms in December 1959 and January 1960 was included in the 1959 Report. 
In June a tornado passing directly over a tower on a newly constructed 230-kv 
line in the Sarnia area demolished the tower and brought down six other towers, 
three on either side. A temporary bypass was established in four days; the 
towers were rebuilt and the circuit was restored to normal service in ten days. 







THE HYDRO-ELECTRIC POWER COMMISSION OF ONTARIO 

POWER DEMANDS AND RESOURCES 
NORTHERN ONTARIO PROPERTIES- NORTHEASTERN DIVISION 

KILOWATTS 
cnn nnn 


DEC 


EMBEk utrtNUABLt r tAis. UArAUi i t 

of power purchased 

of Commission generating stations 






— • — DECEMBER PRIMARY PEAK REQUIREMENTS 






" 


— 300.000 

— 200,000 

— 100,000 


























' 






>' 














— 


y 


1 1 1 1 1 

1940 1945 1950 1955 1960 



Operations — Northern Ontario Properties 



13 



NORTHERN ONTARIO PROPERTIES 

In the Northeastern Division, one 20,000-kilowatt unit was placed in 
service at Red Rock Falls Generating Station in November 1960 and the second 
early in January 1961. The efficiency of Abitibi Canyon Generating Station was 
increased following the deepening of the river channel at Eleanor Rapids and the 
consequent improvement of tailrace conditions at the station. 

The primary peak demand for the Northeastern Division occurred on 
December 21, and exceeded the 1959 peak by only 0.3 per cent. Primary energy 
made available was up by 2.2 per cent, and primary and secondary energy com- 
bined was up from 1959 levels by 4.2 per cent. 

In the Northwestern Division where substantial amounts of surplus hydro- 
electric energy were available, large blocks of secondary energy were sold for 
use in industrial boilers, and sales to the Manitoba Hydro- Electric Board and 
to the Minnesota-Ontario Paper Company were expanded as much as possible. 
The Commission received credit from the Manitoba Board for energy produced 
by the Board from water diverted from Lake St. Joseph via the English and 
Winnipeg Rivers. 







THE HYDRO-ELECTRIC POWER COMMISSION OF ONTARIO 

POWER DEMANDS AND RESOURCES 
NORTHERN ONTARIO PROPERTIES - NORTHWESTERN DIVISION 

KILOWATTS 




of power purchased 

of Commission generating stations 








500.000 




i 


— . — *PRIMARY PEAK REQUIREMENTS 




A 


Pi 

* 


/ 






— 300.000 

— 200.000 

— 100.000 




r-j 












^ 


V 


/ 






, 






























-—>' 






1 1 1 1 1 

1940 1945 1950 1955 1960 

'Maximum peak recorded between September and December each year 



16 



Operation of the Systems 




When the Manitoba Hydro-Electric Board on December 1 operated its 
system in parallel with the system of the Saskatchewan Power Corporation, an 

interconnected 115-kv power 
network was completed, ex- 
tending approximately 1,000 
miles from Manitouwadge 
near the eastern limit of the 
Northwestern Division on 
the east to Saskatoon on the 
west. 

The primary peak de- 
mand in the Northwestern 
Division occurred on Sep- 
tember 22 and was 3.9 per 
cent below the June maxi- 
mum in 1959. The Decem- 
ber peak load was 1.5 per 
cent below the December 
peak in 1959. Annual pri- 
mary energy requirements 
in the Northwestern Divi- 
sion declined by 0.1 per cent 
from 1959 levels, but a 23.1 
per cent increase in produc- 
tion of secondary energy 
resulted in a 3.6 per cent increase in primary and secondary loads combined. 

On December 1, 1960 a violent hydraulic disturbance demolished the super- 
structure at the Aguasabon Generating Station intake close to the shore of Hays 
Lake north of Lake Superior near Terrace Bay. Apparently a restriction in flow 
through the intake ports, due to the accumulation of ice on the racks, lowered 
the level of water in the vertical shaft and resulted in the formation of an air bubble 
in the tunnel. The eventual sudden release of the compressed bubble up the 
vertical shaft evidently created the violent disturbance that caused the damage. 
The wreckage was cleared away by December 9 and the units at the station 
were back in service by December 12. In the interim, one unit was operated 
most of the time as a synchronous condenser to maintain voltage at a satisfactory 
level. 



TRANSFORMER STATION MAINTENANCE — On-site repairs are 
now made to large transformers under shelter provided by portable 
equipment. This transformer has been removed from its tank. 
When it is lowered to the ground, and the scaffolding shown has 
been moved into position, the whole will be covered by a protective 
tarpaulin. 



MAINTENANCE OF THE SYSTEMS 



Electrical Maintenance 

Maintenance of electrical station equipment was carried out according to 
schedule. Failure of major equipment was confined to nine transformers of 



Maintenance of the Systems 



17 



transmission voltage and ten transformers of subtransmission voltage, 
generators with capacities under 10,000 kva required rewinding. 



Three 



During the year a method was convincingly demonstrated for saving repair 
time and costly shipping charges by carrying out on-site repairs to large power 
transformers even when no permanently installed facilities are available. 
Mobile cranes remove the core and winding assembly from the tank. A tem- 
porary scaffolding with a tarpaulin cover protects the unit while the necessary 
maintenance work is done at the site. 



In view of the unprecedentedly high short-circuit currents being developed 
on the Commission's sys- 
tems, it is of particular in- 
terest to note that a test 
position has been established 
so that operating experience 
with high -voltage circuit - 
breakers can be obtained with- 
out hazard to the system. The 
value of this installation both 
to the Commission and to 
equipment manufacturers has 
been amply demonstrated in 
recent tests of a new type of 
air-blast circuit-breaker. 

Mechanical Maintenance 

Major structural repairs 
were carried out during the 
spring on part of the tailrace 
tunnels at 'Toronto Power" 
Generating Station in Niagara 
Falls. Twin concrete-lined 
tunnels running the length of 
the station are situated 150 
feet below the level of the 
upper river. They carry the 
discharge from the station's 
eleven turbines into a single 
brick-lined tunnel which then 
carries it a further 1,800 feet 
to a point of discharge under 

the falls. Many problems were encountered in transporting equipment, concrete, 
and other materials to the tunnel level through restricted access openings. 
Repair work included removing part of the concrete lining in damaged areas, 
excavation of loose bed-rock, drilling and grouting for the insertion of rock 
anchors and dowels, and the placing of reinforcing steel and new concrete. The 
entire operation required the station to be shut down for onlv three weeks. 




AIR-BLAST CIRCUIT-BREAKER — This breaker, with an interrupting 
capacity of 20 million leva, is installed at Burlington Transformer 
Station, a focal point in the Commission's 230-kv network. These 
breakers, the largest of their type being manufactured, are in the 
final stages of field testing at a test position established by the 
Commission for this purpose. 



IS 



Operation of the Systems 



Lines 

A three-year program of repairing conductors was continued on the 230-kv 
lines bringing power westward from sources on the Gatineau River. During 
I960, al 140 towers over a transmission line distance of 30 miles, cable-type 
dampers were replaced with more modern torsion-type dampers. Repairs to 
tower footings at the Ottawa River crossing on 230-kv lines from Paugan 

Generating Station were be- 
gun in the autumn of 1960. 
The weight on each tower 
footing was transferred to a 
specially designed support 
while the old piers were de- 
molished and new piers were 
constructed. 



The Commission's heli- 
copters operated for a total 
of 3,770 hours during the year, 
patrolling approximately 
157,000 miles of high-voltage 
transmission lines, spraying 
approximately 6,300 acres of 
right of way for the control 
of herbaceous growth, and 
carrying out surveying and 
associated duties. A Sikorsky 
S55 helicopter was purchased 
in April 1960 for surveying 
and spraying operations. 
When tested also for use in 
sky-wire stringing, the Sikor- 
sky S55 demonstrated the 
feasibility and economy of 
this operation, particularly 
over rough terrain. 




REHABILITATION OF TOWER FOOTINGS — Beginning in the 
autumn of 1 960, tower footings on one of the Commission's 
oldest 230-kv steel-tower lines across the Ottawa River were 
being replaced. The procedure is to use a 15-inch I-beam, sup- 
ported by the wood-pole structure shown, to temporarily carry the 
weight of one leg of the tower while the old footing is demolished 
and the new one prepared. 



As part of the planned pole replacement program, nearly 12,000 transmis- 
sion, distribution, and communication poles were installed by maintenance crews. 
A continuing program of rehabilitation of steel towers on which galvanizing had 
deteriorated involved the cleaning and painting of over 400 towers. 



Line Maintenance 



1«> 



Forestry 

Over 42,800 acres were chemically treated for the control of woody growth 
during 1960, including the 6,300 acres sprayed by helicopter. A wind gauge 
using hydrogen-filled balloons, and 
developed especially for the pur- 
pose, was of material assistance in 
aerial spraying operations. Tree 
pruning and removal were carried 
out as required on 12,500 miles 
of the Commission's transmission 
and distribution lines, and on 
approximately 780 miles of newly 
constructed or municipally owned 
line. The reforestation program 
included the planting of nearly 
144,000 seedling trees on 189 acres 
of Commission-owned properties 
in the Eastern, Northeastern, and 
Northwestern Regions. 



The rural maintenance line- 
clearing program was curtailed to 
some extent because of the ex- 
tensive repairs required following 
the ice storms of late 1959 and 

earlv 1960 in the West Central This wind-speed and wind-direction indicator was developed 

_ for the guidance of crews engaged in spraying transmission 

Central, and Georgian Bay |j ne rights of way by helicopter. The meteorological 
Regions. balloon, tethered by a nylon line, is held at the helicopter 

flight level to indicate whether wind conditions are favour- 
able for spraying operations. 




SECTION II 



FINANCE 



THE general administrative bases upon which service is provided to the 
Southern Ontario System and the Northern Ontario Properties are out- 
lined on page 2 of the Foreword to this Report. The balance sheets and 
operating statements for the two systems are included in this section together 
with a statement of funded debt and a schedule of Provincial advances out- 
standing. Supporting schedules are to be found in Appendix II beginning, for 
the Southern Ontario System, on page 100, and for the Northern Ontario Proper- 
ties, on page 136. The two statements of the allocation of the cost of primary 
power in Appendix II itemize for each cost-contract municipality its share of the 
total costs incurred and the amount billed under its interim rate. The financial 
operating results for the municipal electrical utilities are reported in the municipal 
service supplement included at the end of the Report. 

20 



Operating Results — 1960 21 

Rate Review 

Over the years the Commission has steadfastly continued its efforts to hold 
the line against inflationary pressures, but increased interest charges, rising 
rates for labour, and higher taxation, together with higher prices for materials, 
have cumulative effects on cost that are ultimately inescapable. Another con- 
tributing factor to the increase in power costs is the increase in reserve generating 
capacity carried. This reserve has been gradually increased until, in 1960, it 
was almost 12 per cent of primary peak requirements in the interconnected 
Southern Ontario System and Northeastern Division. In the Northwestern 
Division, however, the reserve over peak requirements was abnormally high, 
principally as a result of a slackening in the rate of growth in the pulp and paper 
industry. 

To meet increased costs in 1960 it was necessary in the Southern Ontario 
System to revise interim rates upward for the majority of the municipal electrical 
utilities, to introduce a minimum annual energy charge for summer cottage 
customers, and to increase rates for certain direct industrial customers. In 
the Northern Ontario Properties, rates to the majority of the municipal utilities 
were unchanged, the minimum annual energy charge for summer cottage 
service was introduced, and towards the end of the year a general increase of 
$3.50 per kilowatt was introduced for service to direct industrial customers, 
the first general increase affecting direct industrial customers anywhere in the 
Province in nearly eight years. In establishing interim rates for 1961 to cost- 
contract utilities throughout the Province, consideration was given to the 
anticipated effect on costs of certain operating economies and of prospective 
substantially increased sinking fund relief where applicable. 

Data Processing 

The Commission has made considerable progress in installing an integrated 
and centralized system of data processing using a large-scale electronic computer. 
By June 1960 all of the Commission's rural and local system customers were 
being billed by the data processing equipment. Procedures for the transfer of 
payroll and other personnel information were issued during the year and the 
actual transfer of this work to the computer will be completed in 1961. A 
preliminary study of the processing of inventory data was commenced during the 
year. In addition there was a continuous increase in the use of the equipment 
for extensive computations and studies and for the solution of engineering and 
scientific problems. 



COMBINED SYSTEMS 1960 

Operating Results 

Gross revenue from the sale of primary power and energy amounted to 
$230,981,944 in 1960, exceeding that of 1959 by $16,301,545, or 7.6 per cent. 
This revenue was derived from municipal electrical utilities and interconnected 
systems purchasing power for resale, from industrial customers served directly 
by the Commission, and from customers served by Commission-owned local and 
rural distribution facilities. 



22 



Finance 




DOUGLAS POINT NUCLEAR POWER STATION — By December 1960 the 2,300-acre site provided by the 

Commission on the shore of Lake Huron was a centre of construction activity. Stores and construction buildings 

can be seen in the middle of the cleared area, and in the foreground is the site for the station itself. 

The cost of providing service was $228,636,934, an increase over 1959 of 
$16,801,874, or 7.9 per cent. Increased fixed costs arising from additions to 
capital in service, and a change from a net withdrawal to a net provision for 
stabilization of rates and contingencies were the main factors contributing to 
this increase. 

The demand for electric power expressed in terms of the average of monthly 
peak loads rose by 4.5 per cent over that of 1959. The average cost of supplying 
primary power to all customers also increased, the average to cost-contract 
municipal electrical utilities rising from $37.55 per kilowatt in 1959 to $39.18 
per kilowatt in 1960. Increased costs attributable to factors previously men- 
tioned were, however, partly offset by reductions in cost per kilowatt for 
operation, maintenance, and administrative expenses. 

In the process of adjusting the revenue received to the cost of providing 
service in 1960, an amount of $2,345,010 was disposed of as follows: 

Credited to municipalities on annual adjustment — 

Southern Ontario System $1,673,330 

Northern Ontario Properties 92,061 

Credited to Rural Power District stabilization of rates reserve, 

Southern Ontario System 944,626 

Transferred to Statement of Deficit, Northern Ontario Properties. . 365,007 



$2,345,010 



Summary of Financial Position 



23 



Financial Summary 

The Commission's total assets at December 31, 1960, after eliminating the 
intersystem account, were $2,660,258,017 as compared with $2,548,267,695 at 
December 31, 1959. The long-term debt at December 31, 1960 was $1,844,056,308, 
an increase of $58,195,772 during the year. Capital of $495,900,367 at the end 
of 1960 comprised $380,725,102 contributed through sinking fund for the pur- 
pose of retiring long-term debt and $115,175,265 in Provincial contributions for 
assistance in construction of rural distribution facilities. 

The gross expenditure on fixed assets during 1960 was, with the single excep- 
tion of 1955, the lowest in the last twelve years and amounted to $132,039,438, 
of which 62.5 per cent was for power generating facilities. The extension or 
improvement of rural distribution facilities required the expenditure of 
$17,687,139, or 13.4 per cent of the total gross expenditure on fixed assets, while 
transmission facilities accounted for 9.3 per cent, transformation for 12.6 per 
cent, and other facilities, including administrative and service buildings and 



THE HYDRO-ELECTRIC POWER COMMISSION OF ONTARIO 

FIXED ASSETS, CAPITAL, 
AND LONG-TERM LIABILITIES 



2,000 



FIXED ASSETS AT COST 



LONG-TERM 
LIABILITIES 



CAPITAL 




/ 



/ 



t 



? 



r 



MILLION 
DOLLARS 



2,000 



1.500 



1.000 



24 Finance 

equipment, for the balance of 2.2 per cent. After allowing for sales and retire- 
ments amounting to $19,461,021, there was a net increase of $112,578,417 in the 
investment in fixed assets, bringing the total to $2,360,850,796. This total 
includes $266,583,395 in rural fixed assets. Accumulated depreciation provided 
on fixed assets amounted to $279,810,656 at December 31, 1960. 

Economies have been achieved by rescheduling our construction program, 
postponing any project that can be delayed without adversely affecting operations 
and service. At prevailing high interest rates, borrowing was restricted in 1960 
to S100 million, the lowest level in the past five years, and the expectation is 
that borrowing in 1961 can be held to the same or a somewhat lower level. 

The reserve for stabilization of rates and contingencies was $146,671,705 
at December 31, 1960 as compared with $139,458,376 at December 31, 1959. 
The Commission maintains this reserve as an insurance fund for the protection 
of the municipal electrical utilities, rural customers, and direct industrial cus- 
tomers alike, against such contingencies as sharp swings in economic activity, 
unfavourable stream-flows at hydraulic generating stations, physical catastrophe, 
and risk of foreign exchange loss at maturity of bonds payable in United States 
funds. The reserve is not intended to be used for absorbing normal increases in 
costs. 

The funds required by the Commission for capital investment and other 
purposes in 1960 were obtained from sources as shown in the following table: 



STATEMENT OF SOURCE AND APPLICATION OF FUNDS 
for the Year Ended December 31, 1960 

$ 
'000 omitted 

Funds Provided: 

From issue of $100 million of bonds, net of discount and bond issue expense 97,949 

From operations — 

Charges to cost of power not requiring an outlay of cash: 

Net provision and interest added to reserves for stabilization of rates 
and contingencies, and sinking fund, and to accumulated deprecia- 
tion 74,921 

Provision for frequency standardization 10,946 

Miscellaneous 2,885 

88,752 

From reductions in inventories and work orders 5,934 

Total 192,635 



Funds Applied: 

Expenditures on fixed assets, $132,039,000 less proceeds from sales, etc 127,545 

Retirement of Commission bonds and repayment of Provincial advances.. 40,151 
Purchases of general and sinking fund investments, less proceeds from 

sales and maturities 13,759 

Expenditures on nuclear research 2,055 

Miscellaneous 1 ,540 

Net increase in working capital 7,585 

Total 192,635 



Revenue and Expense — Southern Ontario System 



25 



OPERATING RESULTS BY SYSTEMS 1960 

Southern Ontario System 

The cost of providing service at $188,259,866 was 8.9 per cent greater than 
in 1959, and gross revenue from the sale of primary power and energy at 
$190,877,822 was up by 8.5 per cent. Revenue from the sale of secondary 
electric energy applied as an offset against cost amounted to $8,082,582, of which 
$4,741,830 were derived from 60-cycle secondary export and $3,340,752 from other 
secondary sales. The gross revenue figure and the revenue from secondary 
sales together apply to the 27,795,302,731 kilowatt-hours which are the Southern 
Ontario System's share of total Commission sales, wholesale and retail, as shown 
in the table on pages 96 and 97. 

Operating costs, including the cost of power purchased, declined slightly 
from those in 1959, while the charge for depreciation remained practically un- 
changed, the year-to-year increase being small because the 1959 charge had 
included a special provision of $1,330,255 for the possible early retirement of 
certain older hydraulic generating stations. Interest charges were up by 11.8 per 
cent, frequency standardization charges by 14.5 per cent, and the net provision 
of funds for the retirement of long-term debt exceeded that in 1959 by 7.8 per 
cent. The balance of the increase in the cost of providing service is attributable 
to the provision for stabilization of rates and contingencies, none having been 
made in 1959. This provision is explained in detail in the notes on the allocation 
of the cost of primary power appearing on pages 126 and 127. 

In view of the above, the total cost of power to cost-contract utilities rose 
on the average from $37.68 in 1959 to $39.37 in 1960. Apart from one isolated 




DOUGLAS POINT NUCLEAR POWER STATION — This photograph of a scale model gives a striking impression 

of the station as it will appear when the first large-scale nuclear power unit in Canada is ready for service. 

The reactor is scheduled to go critical late in 1964. 



26 



Finance 




LAKEVIEW GENERATING STATION — During the 1961 navigation season, a minimum of 250,000 tons of 
coal will be stored at the station in preparation for the operation of the first of four scheduled units in 1961. 

instance in which quite unusual operating conditions apply, the maximum cost of 
power charged to any cost-contract municipal electrical utility in the Southern 
Ontario System in 1960 was $49.61 per kilowatt per year as compared with 
$48.22 in 1959. 



Northern Ontario Properties 

The cost of providing service to all customers in the Northern Ontario 
Properties, after a withdrawal of $465,170 from the stabilization of rates and 
contingencies reserve, was $40,377,068, which exceeded the corresponding cost 
in 1959 by 3.6 per cent. Gross revenue from the sale of primary power and 
energy amounted to $40,104,122 in 1960, and while this revenue was $272,946 
less than the cost of providing service, it represented an increase of 3.6 per cent 
over the corresponding revenue in 1959. Revenue from the sale of secondary 
electric energy applied as an offset against cost amounted to $1,108,644. The 
gross revenue figure and the revenue from secondary sales together apply to the 
6,521,946,390 kilowatt-hours which are the Northern Ontario Properties' share 
of the total Commission sales, wholesale and retail, as shown in the table on 
pages 96 and 97. 

Operating costs, including the cost of power purchased, increased 1.5 per 
cent over those in 1959. Interest charges were up 6.7 per cent, while charges for 
depreciation rose by 5.5 per cent over similar charges in 1959. The 1960 net 
provision of funds for the retirement of long-term debt increased over the pro- 
vision in 1959 by 5.1 per cent. The largest single factor contributing to the 
increase in over-all costs was the absence in 1960 of a general withdrawal from 
the stabilization of rates and contingencies reserve, the withdrawal in 1959 being 



Revenue and Expense — Northern Ontario Properties 27 

at the rate of $1 per kilowatt on the average monthly peak load of all customers 
for a total of $903,685. Partly offsetting these increases were declines of 10.4 
per cent in the cost of interchange of power with the Southern Ontario System, 
and of 21.9 per cent in charges for frequency standardization, and an increase of 
$167,846 in the withdrawal from the stabilization of rates and contingencies 
reserve applied to reduce the cost of power to cost-contract municipalities for- 
merly served by the Thunder Bay System. Since the cost of service to these 
latter municipal electrical utilities was substantially greater than the revenues 
they provided, it was again necessary to make this withdrawal from the stabiliza- 
tion of rates and contingencies reserve held specifically for their benefit. In 
1960 the withdrawal of $465,170 from this reserve was equivalent to $6 per 
kilowatt on the average of their monthly peak loads as compared with a with- 
drawal of $297,324 in 1959, or $4 per kilowatt. 

As a result of these factors and other considerations mentioned in the 
notes which accompany the statement of the allocation of the cost of primary 
power (see pages 144 and 145), the total cost of power per kilowatt per year to 
cost-contract utilities in the Northern Ontario Properties rose, on the average, 
from $33.54 in 1959 to $34.67 in 1960. 



28 Finance 

THE HYDRO-ELECTRIC POWER 

SOUTHERN 

BALANCE SHEET 

ASSETS 

Fixed Assets at Cost: 

P.mer System $ 1,659,786,230 

Administrative and service buildings and equipment 32,190,369 

Rural Power District 226,406,241 

$ 1,918,382,840 

Less accumulated depreciation 229,874,079 

$ 1,688,508,761 

Frequency Standardization: 

Cost of completed standardization after charging $157,540,927 
to reserves and cost of power — balance to be written off 
in future years 188,548,084 

Current Assets: 

Cash $ 28,766, 133 

Temporary investments in government and government- 
guaranteed securities, at market value 6,718,732 

Accounts receivable 28,251,921 

Customers' securities on deposit 370,600 

Northern Ontario Properties — current account 1,203,514 



65,310,900 



Inventories Held for Operation, Maintenance, and 
Construction: 

Coal at cost. $ 11,641,023 

Other materials and supplies at cost 11,915,079 

Tools and equipment at cost less depreciation 10,433,575 



Deferred Charges and Other Assets: 

Debenture discount and expense less amounts written off . . .$ 17,007,223 
Deferred work orders and other assets 5,405,954 



33.989,677 



22,413,177 



Reserve Fund Investments: 

Investments held for special reserves at amortized cost 
plus accrued interest (approximate market value 
$107,984,000)— 

Pension fund $ 1 13,901 ,960 

Employer's liability insurance fund 3,198,979 

Employees' savings and insurance fund 355,285 

Investments held for other reserves at amortized cost 
(approximate market value $108,881,000)— 

Stabilization of rates and contingencies 104,897,020 

Sinking fund 8,858,408 



231,211,652 
$ 2,229,982,251 



Auditors' Report 

We have examined the balance sheet of the Southern Ontario System of The Hydro-Electric Power Commission of 
Ontario as at December 31, I960 and the statement of operations for the year ended on that date. Our examination 
included a general review of the accounting procedures and such tests of accounting records and other supporting 
evidence as we considered necessary in the circumstances. 

In our opinion the accompanying balance sheet and statement of operations present fairly the financial position of 
the Southern Ontario System of the Commission as at December 31, 1960 and the results of the operations for the 
year ended on that date. 

CLARKSON. GORDON & CO. 

Chartered Accountants. 
Toronto, Canada, 
May 19, 1961. 



Southern Ontario System — Balance Sheet 29 

COMMISSION OF ONTARIO 
ONTARIO SYSTEM 
AS AT DECEMBER 31, 1960 

LIABILITIES, RESERVES, AND CAPITAL 

Long-term Liabilities (including $1,868,306 maturing in 
1961): 

Funded debt (at par of exchange) $ 1,830,200,500 

Less — issued to finance Northern Ontario Properties, a 

separate trust operated by the Commission 309,800,545 

$ 1,520,399,955 
Advances from the Province of Ontario (at par of 

exchange) .$15,060,978 

Less advances for Northern Ontario Properties 2,656,218 

12,404,760 

$ 1,532,804,715 
Less exchange discount (net) incurred on funded debt 

payable in United States funds 670,003 

$ 1,532,134,712 

Current Liabilities: 

Accounts and payrolls payable and accrued charges $ 25,453,052 

Customers' deposits 926,133 

Interest accrued on long-term liabilities 17,944,354 

44,323,539 

Special Reserves: 

Pension fund $ 115,499,666 

Employer's liability insurance fund 3,081,061 

Employees' savings and insurance fund 350,015 

118,930,742 

General Reserve: 

Stabilization of rates and contingencies 127,347,803 



Capital: 

Sinking fund reserve: 
Represented by — 

Funded debt and Provincial advances 

retired through sinking funds $302,902,267 

Sinking fund investments 8,822,099 

$ 311,724,366 

Contributed capital: 

Province of Ontario, assistance for rural construction.. . 95,521,089 

407,245,455 



$ 2,229,982,251 



Note: Commitments under uncompleted contracts for the construction of fixed assets, 
approximately $65,000,000. 



30 Finance 

NORTHERN ONTARIO 

Held and Operated by The Hydro-Electric Power Commission of Ontario in 

BALANCE SHEET 

ASSETS 

Fixed Assets at Cost: 

Power System . $ 398,938,529 

Administrative and service buildings and equipment 3,352,273 

Rural Power District 40,177,154 

$ 442,467,956 

Less accumulated depreciation 49,936,577 

$ 392,531,379 

Frequency Standardization: 

Cost of completed standardization after charging $1,280,489 

to cost of power — balance to be written off in future years. . 3,445,863 



Current Assets: 

Cash $ 503,950 

Accounts receivable 5,751,851 

Customers' securities on deposit 1,556,067 

7,811,868 



Inventories Held for Operation, Maintenance, and 
Construction : 

Materials and supplies at cost $ 923,813 

Tools and equipment at cost less depreciation 526,851 



Deferred Charges and Other Assets: 

Debenture discount and expense less amounts written off $ 3,676,693 

Account receivable in annual instalments 1961-1989 1,761,616 

Deferred work orders and other assets 643,456 



1,450,664 



6,081,765 



Reserve Fund Investments: 

Investments held for reserves at amortized cost (approximate 
market value $16,675,000)— 

Stabilization of rates and contingencies $ 17,009,730 

Sinking fund 2,888,043 



19,897,773 



Deficit: 



Arising from supply of power to customers served for the account 

of the Province of Ontario 259,968 



$ 431,479,280 
Auditors' Report 

We have examined the balance sheet of the Northern Ontario Properties held and operated by The Hydro-Electric 
Power Commission of Ontario in trust for the Province of Ontario and municipalities supplied with power at cost, as 
at December 31. 1960, and the statements of operations and deficit for the year ended on that date. Our examination 
included a general review of the accounting procedures and such tests of accounting records and other supporting 
evidence as we considered necessary in the circumstances. 

In our opinion the accompanying balance sheet and statements of operations and deficit present fairly the financial 
position of the Northern Ontario Properties as at December 31, 1960 and the results of the operations for the year 
ended on that date. 



Toronto, Canada. 
May 19, 1961. 



CLARKSON, GORDON & CO. 

Chartered Accountants. 



Northern Ontario Properties — Balance Sheet 31 

PROPERTIES 

Trust for the Province of Ontario and Municipalities Supplied with Power at Cost 
AS AT DECEMBER 31, 1960 

LIABILITIES, RESERVES, AND CAPITAL 

Long-term Liabilities (including $226,316 maturing in 1961): 

Funded debt (at par of exchange) $ 309,800,545 

Advances from the Province of Ontario (at par of exchange). . . . 2,656,218 

$ 312,456,763 
Less exchange discount (net) incurred on funded debt 

payable in United States funds 535,167 

— $ 311,921,596 



Representing the portion of the funded debt and advances from 
the Province of Ontario owing by The Hydro-Electric Power 
Commission of Ontario, issued to finance Northern Ontario 
Properties. 

Current Liabilities: 

The Hydro-Electric Power Commission of Ontario — current 

account $ 1,203,514 

Accounts and payrolls payable and accrued charges 1,909,326 

Customers' deposits 4,377,171 

Interest accrued on long-term liabilities 3,890,300 

Rural Power District grants received in advance 198,559 



11,578,870 

General Reserve: 

Stabilization of rates and contingencies 19,323,902 

Capital: 

Sinking fund reserve: 

Province of Ontario $ 54,669,977 

Municipalities supplied with power at cost. . . . 14,330,759 



-$ 69,000,736 



Represented by — 

Funded debt and Provincial advances retired 

through sinking funds $ 66,157,298 

Sinking fund investments 2,843,438 



$ 69,000,736 



Contributed capital: 

Province of Ontario, assistance for rural construction 19,654,176 



88,654,912 
$ 431,479,280 



32 



Finance 



THE HYDRO-ELECTRIC POWER COMMISSION OF ONTARIO 

SOUTHERN ONTARIO SYSTEM 

STATEMENT OF OPERATIONS 

for the Year Ended December 31, 1960 



Cost of Primary Power: 

Cost of power purchased 

Operation, maintenance, and administrative 

expenses 

Interest (including interest on long-term liabilities 
and reserves, less interest earned on invest- 
ments) 

Frequency standardization : 

I nterest 

Portion of cost written off 

Depreciation 

Stabilization of rates and contingencies provision: 

General 

Nuclear research 

Sinking fund provision — contribution to system 
capital 



Interchange of power with Northern Ontario 

Properties 

Sale of 60-cycle secondary export energy 

Sale of other secondary energy 

Credit resulting from matured sinking fund. . . 



Net cost of power supplied to Rural Power 
District 



Total 



Amounts Billed for Primary Power: 

Municipalities (at interim rates) 

Direct industrial customers and interconnected 

systems 

Local distribution system customers 

Rural customers 



Total 



Excess of amounts billed over cost 

Credited to municipalities on annual adjustment 
Credited to stabilization of rates reserve 



Power 

System 



12,586,660 
51,101,847 

60,055,602 

7,487,076 
10,805,643 
13,074,301 

4,448,929 
407,520 

16,250,362 



176,217,940 

4,503,699 

4,741,830 

3,340,752 

841,201 



162,790,458 
20,634,771 



Rural Power 
District 



13,185,322 



4,772,499 



6,213,824 



1,297,763 



Total 



25,469,408 



25,469,408 
20,634,771 



142,155,687 



118,555,785 

25,182,780 
90,452 



143,829,017 



1,673,330 
1,673,330 



46,104,179 



47,048,805 



47,048,805 



944,626 
944,626 



12,586,660 
64,287,169 

64,828,101 

7,487,076 
10,805,643 
19,288,125 

4,448,929 
407,520 

17.548.125 



201,687,348 

4,503,699 

4,741,830 

3,340,752 

841,201 



188,259,866 



188,259,866 



118,555,785 

25,182,780 

90,452 

47,048,805 



190,877,822 



2,617,956 

1,673,330 

944,626 



Statements of Operations 
NORTHERN ONTARIO PROPERTIES 

Held and operated by The Hydro-Electric Power Commission of Ontario in trust for the 
Province of Ontario and municipalities supplied with power at cost 

STATEMENT OF OPERATIONS 
for the Year Ended December 31, 1960 



33 



Customers served for the account 
of the Province of Ontario 



Rural 
Power 
District 



Other 
customers 



Total 



Munici- 
palities 
supplied 
with power 
at cost 



Total 



Cost of Primary Power: 

Cost of power purchased 

Operation, maintenance, and ad- 
ministrative expenses 

Interest (including interest on long- 
term liabilities and reserves, less 
interest earned on investments). 

Frequency standardization: 

Interest 

Portion of cost written off 

Depreciation 

Provision for nuclear research 

Sinking fund provision — contribu- 
tion to system capital 



2,123,827 



777.939 



1,102,050 
209,336 



$ 
480,206 

13,418,335 



13,222,074 

176,850 

140,038 

2,909,229 

92,480 

3,518,902 



$ 
480,206 

15,542,162 



14,000,013 

176,850 

140,038 

4,011,279 

92,480 

3,728,238 



$ 
480,206 

15,542.162 



14,000,013 

176,850 

140,038 

4,011,279 

92,480 

3,728,238 



Interchange of power with Southern 
Ontario System 

Sale of secondary energy 

Credit resulting from prepaid and 
matured sinking funds 



4,213,152 



33,958,114 

4,503,699 
1,108,644 

724,083 



38,171,266 

4,503,699 
1,108,644 

724.083 



38,171,266 

4,503,699 
1,108,644 

724,083 



Cost of power to municipalities 
supplied at cost 

Cost of power supplied to Rural 
Power District 

Withdrawal from stabilization of 
rates reserve 



4,213,152 



2,698,478 



36,629,086 
4,832,360 
2,698,478 



40,842,238 
4,832,360 



40,842,238 



4,832,360 



465,170 



465,170 



Costs after withdrawal from 
stabilization of rates reserve .... 

Amounts BilledforPrimaryPower : 
Municipalities supplied with power 

at cost (at interim rates) 

Fixed-rate municipalities 

Direct industrial, and other cus 

tomers 

Local distribution system customers 
Rural customers 



6,911,630 



29,098,248 



36,009,878 



4,367,190 



40,377,068 



4,459,25: 



1,232,224 

24,883,132 
3,045,900 



6,483,615 



1,232,224 

24,883,132 
3,045,900 
6,483,615 



4,459,251 
1,232,224 

24,883,132 
3,045,900 
6,483,615 



Total 



6,483,615 



29,161,256 



35,644,871 



4,459,251 



40,104,122 



Excess or deficiency of amounts billed 
over cost 



428,015 



63,008 



365,007 



Credited to municipalities on an 
nual adjustment 



92,061 



92,061 



272,946 
92,061 



Transferred to Statement of Deficit 



365,007 



365,007 



Statement of Deficit for the Year Ended December 31, 1960 

Balance at credit January 1, 1960 

Deduct balance transferred from Statement of Operations 

for the year ended December 31, 1960 

Balance at debit December 31, 1960 



$ 105,039 

365,007 
$ 259,968 



34 



Finance 



THE HYDRO-ELECTRIC POWER 
FUNDED DEBT AS AT 



Date of maturity 


Callable on 


or after 


Date of issue 


Interest rate 


PAYABLE IN CANADIAN FUN 


ds — Guaranteed as to princ 


ipal and interest by the Province of Ontario: 


February 
March 


15, 1962 






February 15, 1957 
March 1, 1948 


per cent 
3 


1, 1963 


March 


1, 1961 


March 


1, 1963 


March 


1, 1962 


March 1, 1955 


3 


October 


15, 1963 






October 15, 1958 


4 


May 


15, 1964 




November 15, 1957 


5 


May 


15, 1964 


May 


15, 1962 


May 15, 1954 


3 


July 


2, 1964 


July 


2, 1960 


July 2, 1948 


3 


October 


15, 1964 


October 


15, 1963 


October 15, 1956 


4^ 


April 


1, 1965 


April 


1, 1964 


April 1, 1957 


5 


December 


15, 1965 


December 


15, 1963 


December 15, 1948 


3 


January 


15, 1966 


January 


15, 1964 


January 15, 1956 


3M 


March 


1, 1966 


March 


1, 1965 


March 1, 1958 


4 


May 


1, 1966 


May 


1, 1964 


May 1, 1951 


3H 


January 


15, 1967 


January 


15, 1965 


January 15, 1952 


4 


March 


15, 1967 


March 


15, 1964 


March 15, 1953 


4M 


April 


1, 1967 


April 


1, 1965 


April 1, 1949 


3 


April 


1, 1967 


April 


1, 1964 


April 1, 1947 


2% 


November 


1, 1967 


November 


1, 1964 


November 1, 1952 


4M 


November 


1, 1967 


November 


1, 1964 


November 1, 1952 


' 434 


January 


15, 1968 


January 


15, 1966 


July 15, 1949 


3 


April 


15, 1968 


April 


15, 1966 


April 15, 1952 


4 


October 


1, 1968 


October 


1, 1965 


October 1, 1947 


2% 


July 
July 


1, 1969 






July 1, 1959 
July 15, 1953 


5% 
4M 


15, 1969 


July 


15, 1966 


July 


15, 1969 


July 


15, 1966 


July 15, 1953 


4^ 


November 


1, 1969 


November 


1, 1967 


November 1, 1949 


3 


January 

February 

April 


1, 1970 






January 1, 1930 
February 15, 1960 


4% 


15, 1970 




6 


1, 1970 


April 


1, 1968 


April 1, 1950 


3 


July 


15, 1970 






July 15, 1960 


5H 


October 


15, 1970 


October 


15, 1969 


October 15, 1958 


43^ 


June 


1, 1971 


June 


1, 1961 


June 1, 1946 


2% 


June 


15, 1973 


June 


15, 1971 


June 15, 1950 


3 


July 


15, 1974 


July 


15, 1972 


July 15, 1956 


4 


October 


15, 1974 


October 


15, 1972 


October 15, 1956 


43^ 


August 


15, 1975 


August 


15, 1972 


February 15, 1957 


m 


January 


15, 1976 


January 


15, 1974 


January 15, 1956 


4 


November 15, 


November 


15, 1974 


November 15, 1957 


5 


March 


1, 1977 


March 


1, 1975 


March 1, 1955 


sy 2 


April 


1, 1977 


April 


1, 1974 


April 1, 1957 


5 


March 


1, 1978 


March 


1, 1976 


March 1, 1958 


4^ 


October 


15, 1978 


October 


15, 1976 


October 15, 1958 


5 


May 


15, 1979 


May 


15, 1974 


May 15, 1954 


3V 2 


July 


1, 1979 






July 1, 1959 
October 15, 1954 


5% 


October 


15, 1979 


October 


15, 1974 


sy 2 


February 


15, 1980 


February 


15, 1978 


February 15, 1960 


6 


July 


15, 1980 


July 


15, 1978 


July 15, 1960 


sy 2 



Statement of Funded Debt 



35 



COMMISSION OF ONTARIO 
DECEMBER 31, 1960 



Principal outstanding December 31, 1960 



Southern Ontario System 


Northern Ontario Properties 


Total 


$ 
8,367,500 


2,990,000 


$ 
11,357,500 


22,324,000 


7,343,000 


29,667,000 


22,651,000 




22,651,000 


12,948,000 


6,700,000 


19,648,000 


3,584,500 


9,598,000 


13,182,500 


12,736,500 


902,000 


13,638,500 


25,052,500 


13,371,500 


38,424,000 


12,999,500 




12,999,500 


16,331,500 


1,716,000 


18,047,500 


43,022,000 




43,022,000 


10,890,500 


2,016,500 


12,907,000 


29,763,500 


6,157,500 


35,921,000 


22,427,000 


5,011,000 


27,438,000 


44,632,000 


412,500 


45,044,500 


34,038,000 




34,038,000 


10,651,500 


32,244,000 


42,895,500 


10,410,455 


3,996,545 


14,407,000 


19,225,500 


1,812,000 


21,037,500 


30,716,000 




30,716,000 


36,178,000 


6,300,000 


42,478,000 


44,949,500 




44,949,500 


13,450,000 


5,800,000 


19,250,000 


10,000,000 


3,000,000 


13,000,000 


34,045,000 




34,045,000 


24,343,000 




24,343,000 


37,800,000 


11,500,000 


49,300,000 


11,497,500 




11,497,500 


11,200,000 


4,800,000 


16,000,000 


48,038,000 


5,300,000 


53,338,000 


3,800,000 


1,600,000 


5,400,000 


3,700,000 


1,800,000 


5,500,000 


13,745,000 


4,290,000 


18,035,000 


52,000,000 


2,300,000 


54,300,000 


42,591,000 


7,000,000 


49,591,000 


26,592,500 




26,592,500 


25,063,000 


12,000,000 


37,063,000 


42,500,000 


7,500,000 


50,000,000 


10,875,000 


25,230,000 


36,105,000 


26,200,000 


13,000,000 


39,200,000 


73,400,000 


7,900,000 


81,300,000 


30,080,000 


6,400,000 


36,480,000 


33,000,000 


16,500,000 


49,500,000 


31,500,000 


3,500,000 


35,000,000 


28,000,000 


9,000,000 


37,000,000 


41,975,000 


8,000,000 


49,975,000 


23,800,000 


10,200,000 


34,000,000 


31,200,000 


13,400,000 


44,600,000 


1,204,293,955 


280,590,545 


1,484,884,500 



46 



Finance 



THE HYDRO-ELECTRIC POWER 
FUNDED DEBT AS AT 



Date of maturity 



Callable on or after 



Date of issue 



Interest rate 



PAYABLE IN UNITED STATES 



March 

March 

March 

March 

May 

September 

February 

November 

March 

May 

February 



15, 
15, 
15, 
15, 
15, 



1961 
1962 
1963 
1964 
1971 
1972 
1975 
1978 
1980 
1981 
1984 



funds — Held by 
March 15, 

March 15, 

March 15, 

March 15, 

May 



Province of Ontario and having terms identical with 



September 1, 
February 1 , 
November 1, 
March 15, 

May 15, 

February 1, 



1959 
1959 
1959 
1959 
1956 
1956 
1958 
1958 
1959 
1961 
1969 



March 
March 
March 
March 
May 



15, 
15, 
15, 
15, 
15, 



September 1, 
February 1, 
November 1, 
March 15, 

May 15, 

February 1, 



1954 
1954 
1954 
1954 
1951 
1951 
1953 
1953 
1954 
1956 
1959 



2.65 
2.70 

2.75 
2.80 

3M 
3M 

4H 



Total funded debt (at par of exchange) 



Summary of changes in funded debt 



Outstanding at January 1, 1960 
Less redemptions during year . . 



Add new bond issues during year. . 
Outstanding at December 31, 1960 



ADVANCES FROM THE PROVINCE OF 

Repayable to the Province in accordance with the terms of Province 



Date of maturity 


Description 


Interest rate 


May 15,1961-1968 

May 15, 1961-1970 


Annuity bonds 
Annuity bonds 
Annuity bonds 
Annuity bonds 


per cent 
4 

4^ 
4M 
4 


January 15, 1961-1971.... 


June 1, 1961-1971 



Total advances (at par of exchange) 



Summary of changes in advances from the Province 

Balances of advances at January 1, 1960 

Less repayments during year 

Balances of advances at December 31, 1960 



Statement of Funded Debt 
COMMISSION OF ONTARIO 
DECEMBER 31, 1960 Concluded 



37 



Principal outstanding December 31, 1960 



Southern Ontario System | Northern Ontario Properties 



Total 



issues sold in the United States by the Province of Ontario on behalf of the Commission: 



696,000 




696,000 


1,434,000 




1,434,000 


2,544,000 




2,544,000 


2,599,000 




2,599,000 


46,406,000 


2,890,000 


49,296,000 


43,175,000 




43,175,000 


47,696,000 




47,696,000 


43,966,000 


5,000,000 


48,966,000 


29,920,000 




29,920,000 


41,070,000 


3,320,000 


44,390,000 


56,600,000 


18,000,000 


74,600,000 


316,106,000 


29,210,000 


345,316,000 


1,520,399,955 


309,800,545 


1,830,200,500 



during year ended December 31, 1960 

$1,473,065,455 
22,665,500 



$1,450,399,955 

70,000,000 

$1,520,399,955 



$283,583,545 

3,783,000 

$279,800,545 

30,000,000 

$309,800,545 



$1,756,649,000 

26,448,500 

$1,730,200,500 

100,000,000 

$1,830,200,500 



ONTARIO AS AT DECEMBER 31, 1960 

of Ontario bonds issued in part for the purposes of the Commission 



Balances of advances outstanding December 31, 1960 
{Payable in Canadian, United States, or Sterling funds) 



Southern Ontario System 


Northern Ontario Properties 


Total 


$ 
3,989,687 
3,602,585 
2,125,896 
2,686,592 

12,404,760 


$ 
269,459 
873,078 
522,209 
991,472 

2,656,218 


$ 
4,259,146 
4,475,663 
2,648,105 
3,678,064 

15,060,978 



of Ontario during year ended December 31, 1960 



$25,039,726 
12,634,966 

$12,404,760 



$5,457,014 
2,800,796 

$2,656,218 



$30,496,740 
15,435,762 

$15,060,978 



SECTION III 



THE COMMISSION'S CUSTOMERS 



THE Commission's interest in the market for electric energy necessarily 
extends beyond the supply of electricity in wholesale quantities to its prin- 
cipal municipal and industrial customers. This wider interest is based on the 
recognition that the maintenance of low rates for electricity is dependent on a 
continued expansion in the use of electricity by ultimate customers served at 
retail by municipal and rural systems. These customers must be encouraged to 
avail themselves as fully as possible of the wide variety of efficient and labour- 
saving electric appliances on the market. In order to achieve this increased 
use of electric equipment, the Commission, in conjunction with the municipal 
electrical utilities and the electrical manufacturers, continued a balanced load- 
building program. 

The Sales Program 

Sales personnel specially qualified for dealing with commercial, industrial, 
and residential aspects of sales, and with electrical applications on the farm 
gave guidance to regional and municipal utility staffs in developing the market 
for electric energy. They also organized and conducted training courses and 
study groups on electric heating, lighting, and the use of electricity in industry. 
During October and November, intensive training in electric heating was given 
to 175 electrical and building contractors, and certification as qualified electric 

38 



The Sales Program 



39 



heating contractors was given to the candidates who successfully completed the 
course. 

Activity in the Medallion Home program was markedly increased, and 
600 homes were awarded the Medallion symbol, 150 the Gold Medallion and 450 
the Bronze Medallion. The Bronze and Gold Medallion standards guarantee to 
the purchaser of a house a high degree of electrical excellence to meet present 
and future electrical needs. Both standards require a service and distribution 
panel of appropriate capacity, basic conditions for adequate lighting through- 
out, an electric water-heater, and circuit provisions for major appliances. In 
addition, to qualify for the Gold Medallion, a house must have electric heating, 
as well as certain items of feature lighting. Negotiations with builders, and 
planners of subdivisions have established a program for approximately 5,500 
Medallion houses to be constructed during the period 1961-2. The Commission 
is sponsoring a competition, open to all members of the Ontario Association 
of Architects resident in the Province, for the design of an all-electric house 
which meets Gold Medallion standards. The award-winning design is expected 
to be displayed at the Canadian National Exhibition in 1961. 

During 1960 a survey by mail of 100,000 customers was undertaken for the 
purpose of establishing appliance saturations to be used in determining market 
trends in appliance sales and load -building potentials. The survey was a repre- 
sentative sampling of 1.5 million residential and farm customers served by 
municipal and rural distribution systems. The response to the questionnaire 
sent out was remarkably high, and the summary and interpretation of the results 
will be available in the summer of 1961. The statistics obtained will be useful 




APPLIANCE DEMONSTRATION CENTRE OF LONDON PUBLIC UTILITIES COMMISSION — The municipal 
utilities are co-operating with the Commission and appliance manufacturers in a continuing program to pro- 
mote electrical living. The tasteful arrangement of convenient, economical, labour-saving household appliances 
provides a centre of customer interest and an opportunity to develop and improve customer relations. 



40 



The Commission's Customers 



in planning residential and farm load-building programs on a province-wide 
basis or for selected areas. 

In order to obtain data which will assist in the planning of distribution 
systems, the Association of Municipal Electrical Utilities of Ontario, in co- 
operation with Ontario Hydro, has undertaken a program of residential load 
surveys. The first step, inaugurated in November 1960, was a pilot survey of 

approximately 200 customers 
selected at random from eight 
municipal utilities in the Metro- 
politan Toronto area. The infor- 
mation on power requirements was 
recorded on digital demand re- 
corders to permit automatic trans- 
lation for data processing by the 
Commission's electronic computer. 
The data, correlated with informa- 
tion on the customers' inventory of 
appliances, will be used in prepara- 




tory work 
surveys. 



for more extensive 



DIGITAL DEMAND RECORDER USED IN RESIDENTIAL 
SURVEY — Fifty recorders of the type instated on this dis- 
tribution line pole have been used in a pilot survey of the 
loads of 200 customers in the Metropolitan Toronto area. 
The plan is eventually to extend the survey to include a 
representative sampling of 1,000 customers throughout the 
Province. 



Special sales programs have 
enlisted the co-operation of builders 
and dealer-contractors in develop- 
ing the water-heater market. Many 
utilities are effectively promoting 
the use of electric water-heaters. 
They are also providing, as the 
Commission provides for its rural 
and other retail customers, a main- 
tenance service for water-heaters 
in conjunction with a choice of 
either a rental or a time-payment 

purchase plan. In all, 42,500 water-heaters were installed during 1960 by the 

Commission and the associated municipal utilities. 

Deliveries of Power in Wholesale Quantities 

The table on page 95 indicates by systems the respective magnitudes of 
the Commission's operations for the delivery of power to municipal systems, 
interconnected utilities, the rural operating areas, and industrial customers 
served directly by the Commission. Deliveries in total during 1960 amounted 
to 34,554,846,788 kilowatt-hours, representing an increase of 7.0 per cent over 
the 1959 total. The municipal electrical utilities and the local systems owned and 
operated by the Commission together received 51.8 per cent of the 1960 deliveries, 
the Commission's direct industrial customers 26.3 per cent, interconnected 
utilities 13.6 per cent, and the rural operating areas 8.3 per cent. The energy 
delivered to direct industrial customers and interconnected utilities included 
9,081,790,355 kilowatt-hours of primary and 4,714,805,404 kilowatt-hours of 



Municipal Electrical Utilities and Local Systems 



41 



secondary energy. The table on deliveries of energy in wholesale quantities is 
supplemented by a table on page 96 which traces the distribution of this energy 
to ultimate customers served either by the Commission or by the associated 
municipal utilities. 

The commentary that follows is confined, with one exception, to the whole- 
sale aspects of the Commission's sales. The exception is the analysis of rural 
distribution which is included with the report on bulk supply to the rural operat- 
ing areas so that the Commission's rural service may be viewed in its entirety. 
Supporting statistics on rural service, the schedule of rates, and a brief description 
of the classes of service are in Appendix III. Retail distribution of electricity 
by the municipal utilities and Commission-owned local distribution systems is the 
subject of the municipal service supplement beginning on page 163. The number 
of ultimate customers served by the Commission and the associated municipal 
utilities in 1960 was 1,881,472. 



MUNICIPAL ELECTRICAL UTILITIES AND LOCAL SYSTEMS 

A total of 382 municipal systems was being served by the Commission's 
transmission line networks at the end of 1960. The Public Utilities Commissions 
of Trafalgar Township and 
Oakville were amalgamated 
as Oakville-Trafalgar Public 
Utilities Commission on July 
1, 1960 by a special Act of the 
Provincial Legislature. Five 
municipalities formerly served 
under fixed-rate contracts in 
the Northeastern Division be- 
came cost-contract customers 
of the Commission during 
1960. The town of Espanola, 
formerly supplied by a private 
company, became a customer 
of the Commission under a 
cost contract effective October 
1, 1960. As a result of these 
changes the number of muni- 
cipalities served under cost 
contracts in the Southern 
Ontario System declined by 1 
to 326, the number in the 
Northern Ontario Properties 
rose by 6 to 24, with 4 muni- 
cipalities, all in the Northern 
Ontario Properties, continu- 
ing to be served under fixed-rate contracts, and 28 in the Province as a whole 
being supplied by local systems owned and operated by the Commission. 




HOME ECONOMISTS CHOOSE THE ELECTRICAL WAY — In a 
program to modernize its techniques for training home economists / 
the University of Toronto installed 1 2 electric surface cooking 
units under a co-operative arrangement made with Ontario Hydro 
and the Toronto Hydro-Electric System. 

During 1960, approximately 650, modern automatic electric 
appliances were placed in over 200 Ontario schools under 
co-operative arrangements of this kind. 



42 



The Commission's Customers 



The municipal electrical utilities are billed monthly at an interim rate per 
kilowatt of peak load. The monthly peak load for a utility is the maximum 
average demand over a period of twenty consecutive minutes in the month. As 
the system peak load usually occurs in December, the peak loads for that month 
are given for these utilities and for local systems in the statistical table (State- 
ment "D") beginning on page 246. The sum of these loads in 1960 was 3,588,542 
kilowatts, an increase of 6.5 per cent over the 3,368,571 kilowatts supplied in 

1959. The energy supplied to the 
municipal utilities and local systems 
during 1960 was 17,907,540,003 kilo- 
watt-hours, an increase of 5.6 per 
cent over the 16,950,730,294 kilo- 
watt-hours supplied in 1959. 



THE HYDRO-ELECTRIC POWER COMMISSION OF ONTARIO 

MUNICIPAL ELECTRICAL UTILITIES 
AND LOCAL SYSTEMS 

PRIMARY POWER AND ENERGY DELIVERED 




1950 1955 1960 

"Maximum monthly sum of the coincident peak loads 



Each of the municipal electrical 
utilities is listed in the tables of 
financial reports and operating 
statistics that form the larger part 
of the municipal service supplement 
beginning on page 163. The books 
of account from which the financial 
information is derived are kept by 
the utilities in accordance with a 
standard accounting system designed 
by the Commission for use by all 
utilities served under cost or fixed- 
rate contracts. These records are 
periodically inspected by the Com- 
mission's municipal accountants and 
from time to time adjustments and 
improvements in accounting and 
orifice routine are recommended as 
the requirements of standardized 
methods may dictate. This type of assistance and supervision is directed 
towards ensuring the correct application of the standard accounting procedure 
and the uniform classification of revenues and expenditures. The work carried 
out by the Commission's municipal accountants on behalf of the municipal 
utilities does not constitute an audit of the accounts. For such an audit the 
municipalities must make their own arrangements. 



DIRECT INDUSTRIAL CUSTOMERS 
AND INTERCONNECTED SYSTEMS 



The industrial customers served directly by the Commission include mines 
in relatively isolated areas, and industrial enterprises of many types whose 
requirements for power may exceed the supply capability of the local municipal 



Direct Industrial Customers and Interconnected Systems 



43 



or rural facilities. The number of customers being so supplied by the Com- 
mission at December 31, 1960 was 211 as compared with 214 at December 31, 
1959. In addition, thirteen independent utilities both within and beyond the 
borders of the Province have contracts with the Commission for the supply or 
interchange of power but these are not industrial customers in the generally 
accepted sense. Their loads are 
therefore not included in the table 
of power and energy supplied to 
industrial customers, or in the his- 
torical chart on this page. 



The sum of the coincident 
primary peak loads of the Com- 
mission's industrial customers 
reached a monthly maximum of 
1,367,708 kilowatts in March 1960, 
thereby registering an increase of 
1.1 per cent over the November 
1959 maximum of 1,352,923 kilo- 
watts. The annual kilowatt-hour 
consumption in 1959 and 1960 is 
given by types of industry in the 
accompanying table, together with 
comparative figures on peak loads 
for both years. Since the peak loads 
in any one month do not offer a 
satisfactory basis for comparing the 
activity of one industry with that 
of another, the table gives the aver- 
age of the monthly peak loads for 
each type of industry. 



THE HYDRO-ELECTRIC POWER COMMISSION OF ONTARIO 

DIRECT INDUSTRIAL CUSTOMERS 
PRIMARY POWER AND ENERGY DELIVERED 



"Power 



Annual Energy r 



T 

1950 1955 1960 

'Maximum monthly sum of the coincident peak loads 



Analysis of Primary Loads by Types of Industry 

Total primary energy consumption by industrial customers served by the 
Commission rose moderately during 1960. Consumption in the steel, electro- 
metallurgical, and abrasives groups continued to move in an upward direction 
but at distinctly lower rates of growth than those prevailing in 1959, while 
consumption in the general manufacturing as well as in the chemical, electro- 
chemical, and cyanamid groups again declined as in 1959, but also at consider- 
ably lower rates. In total annual consumption, the mining sector as a whole 
declined by approximately 4 per cent from last year. There was a sharp reversal 
in the upward trend in energy consumption in uranium, base metals, and non- 
metals mining, but some improvement in energy consumption by gold, silver, and 
cobalt mining. The sharpest increases in rate of growth among the industrial 
customers groups were registered by the miscellaneous group, by the pulp and 
paper companies, and by transportation services and communications, the last 



44 



The Commission's Customers 



Primary Power and Energy Supplied to Direct Industrial 
Customers, by Types of Industry 



Type of industry 



Pulp and Paper 

Mining: 

(a) Gold 

(b) Silver and Cobalt 

(c) Base Metals 

(d) Uranium 

(e) Non-metals 

Quarrying, Cement, and Basic Building 

Materials 

Steel and Electrometallurgical 

Abrasives 

Chemical, Electrochemical, and Cyanamid. . . . 

Grain Elevators and Milling 

Transportation Services and Communications 

Government Services and Institutions 

General Manufacturing 

Miscellaneous 

Total 



Average of the 
monthly peak loads 



Annual energy delivered 











Increase 


1959 


1960 


1959 


1960 


or 
decrease 


kw 


kw 


kwh 


kwh 


per cent 


321,417 


343,533 


2,116,147,111* 


2,282.342.756 


7.9 


88,216 


89,889 


588.023,334 


607,729.896 


3.4 


3.350 


3,710 


16,996.035 


19,068.249 


12.2 


229,890 


221.204 


1,579,973,022 


1.559,451,380 


1.3 


100,636 


86,626 


689,320,107 


577,340,966 


16.2 


6,623 


6,304 


30,070,386 


28.407.210 


5.5 


37,748 


37.017 


218,196,911 


201.212.808 


7.8 


149,866 


153,917 


833.844,337 


852,273,366 


2.2 


67,883 


70.709 


542,296,500 


567,394,120 


4.6 


172.417 


169,721 


1,321,705,925 


1,308,934,983 


1.0 


8,426 


7,968 


30,814.786 


28,512,869 


7.5 


7,151 


9,125 


32,861.526 


40,191,985 


22.3 


24,267 


25,972 


140.380.176 


153.668,498 


9.5 


82,435 


80,058 


382.018.501 


377.563.845 


1.2 


5,521 


7,428 


26,979.934 


38.611.069 


43.1 



1.305,846 1,313,181 



8,549,628.591* 8,642,704,000 



♦Revised to include 9,973,560 kwh transferred from secondary to primary. 

reflecting the expansion of pipeline pumping services in the Province, and sur- 
passing the former maximum established in 1957. The pulp and paper companies 
did not reach the levels of their earlier forecasts which had been in part the basis 
for the Commission's capital development program in northwestern Ontario. 
Nevertheless, the continued and relatively steady expansion in energy use by 
this group of customers was more than sufficient to offset the decline in the 
mining group. 



Primary Loads of Interconnected Systems 

The corresponding primary peak and energy loads of the interconnected 
systems were 54,140 kilowatts in 1960 as compared with 59,924 kilowatts in 
1959, and 439,086,355 kilowatt-hours in 1960 as compared with 427,183,502 
kilowatt-hours in 1959. The peak load was lower than the 1959 peak by 9.7 
per cent, and the energy load was higher by 2.8 per cent. 



Secondary Energy Sales 

Sales of secondary energy amounted in total to 4,714,805,404 kilowatt-hours 
as compared with the revised figure of 3,723,338,310 kilowatt-hours for 1959. 
Sales to interconnected systems rose from 3,372,672,970 kilowatt-hours in 1959 
to 4,267,047,937 kilowatt-hours in 1960, and sales to direct industrial customers 
correspondingly from 350,665,340 kilowatt-hours to 447,757,467 kilowatt-hours. 



Rural Electrical Service 



45 




Typical of the expansion of secondary industry in Ontario is this machining operation being carried out on a 

large steam turbine at a Scarborough manufacturing plant. The turbine, the first of its kind to be manufactured 

in Canada, is to be installed at Thunder Bay Generating Station. 



RURAL ELECTRICAL SERVICE 



The table on page 46 shows that the net increase in miles of rural primary 
distribution lines during 1960 was 545 as compared with a net increase of 913 
miles in 1959. Growth of this magnitude, like the associated net increase in 
number of customers served, falls far short of the annual growth that marked the 
major expansion program of 8 to 12 years ago. It is important to bear in mind, 
however, that expansion of rural facilities in some areas is offset in others by the 
large annexations of rural areas by growing municipalities. The future operation 
of the Rural Power District as a whole cannot avoid being adversely affected by 
the loss to municipal utilities of those areas where load is most heavily concen- 
trated and where revenues are consequently better than average for rural service. 
As a result of annexations of this type the net increase in number of rural cus- 
tomers in 1960 was actually the lowest in sixteen years. During the 1960-61 
period, approximately 40,000 rural customers will be taken over by municipal 
electrical utilities. 

The net increase in number of customers in the Southern Ontario System 
was 12,074 as compared with 14,341 in 1959. Changes in particular regions 
reflect in part administrative redistribution of areas, for example the transfer 
of Oshawa and Bowmanville Rural Operating Areas from East Central to Central 
Region. An extensive annexation of the rural area by the City of Sudbury 



46 



The Commission's Customers 

Rural Power District 

NET INCREASE IN MILEAGE OF PRIMARY LINES AND NUMBER OF 
CUSTOMERS DURING 1960 





Miles of 

primary 

line 






Number of 


customers 








Farm 


Residential 


Com- 
mercial 


Sum 


mer 


Power 




System and Region 


Rural 


Hamlet 


Com- 
mercial 


Other 


Total 


Southern Ontario System 


59.41 
48.60 
7.96 
634.60 
118.96 
449.12 
120.20 


85 

172 

74 

1.765 

85 

1,787 

119 


244 
182 
38 
814 
273 
371 
270 


1.994 
1,401 

745 
5.079 

710 
2,771 
1.570 


167 

73 

50 

723 

152 

430 

61 


15 
6 
9 

48 
100 

64 

17 


56 
265 

46 

272 

1.467 

989 

456 


63 
14 
8 
104 
16 
25 
37 


2,624 


West Central 


1,179 


Niagara 

Central 

Georgian Bay 


822 
8,805 
2,803 
4,331 


Eastern 


2,530 


Total 


443.41 


21 


1,450 


5,926 


650 


259 


3,551 


217 


12,074 


Northern Ontario 
Properties 

Northeastern 

Northwestern 


34.55 
67.50 


67 
64 


154 
154 


4,528 
472 


365 
112 


43 
12 


122 
133 


43 
12 


4,684 
831 


Total 


102.05 


131 


308 


4,056 


253 


55 


255 


31 


3,853 


Total — All systems 


545.46 


110 


1.758 


1,870 


397 


314 


3,806 


186 


8,221 



Italic figures indicate decreases. 



THE HYDRO-ELECTRIC POWER COMMISSION OF ONTARIO 

RURAL POWER DISTRICT 
PRIMARY POWER AND ENERGY DELIVERED 




•Maximum monthly sum of the coincident peak loads of the rural 
operating areas 



accounts in large measure for a 
decline of 4,684 rural customers in 
the Northeastern Region and a net 
decline of 3,853 customers in the 
Northern Ontario Properties as a 
whole. The net increase in total 
customers served was 8,221, bring- 
ing the total number served at 
December 31, 1960 to 499,291, 
including 140,782 farm customers. 
The rural distribution network in- 
cluded 47,896 miles of primary line. 

Load Growth 

The monthly sum of the co- 
incident peak loads in the 100 rural 
operating areas was 647,346 kilo- 
watts in December 1960, showing 
an advance of 7.5 per cent over the 
peak of 602,220 kilowatts in 1959. 
Energy supplied to the areas during 
the year rose by 7.4 per cent from 
2,654,905,492 kilowatt-hours in 1959 
to 2,850,711,026 kilowatt-hours in 
1960. 



Miles of Line and Number of Customers — Rural 



47 



THE HYDRO-ELECTRIC POWER COMMISSION OF ONTARIO 



RURAL POWER DISTRICT 



HET INCREASE 
IN YEAR 



MILES OF PRIMARY LINE 



TOTAL AT 
END OF YEAR 




J 



1935 1940 



T 
1945 



1950 1955 



1960 



NET INCREASE 
IN YEAR 



NUMBER OF CUSTOMERS 



TOTAL AT 
END OF YEAR 




iLon 



T 

1935 



I 

1940 



HH 



1945 1950 



T 

1955 



1960 



48 



The Commission's Customers 



All classes of service showed substantial increases in energy consumption 
ranging from 5.7 per cent for farm service to 13.2 per cent for industrial power 
service. The increase in farm service consumption, which was associated with 
.i slight decline in the number of farm customers, is reflected in a 5.4 per cent 
increase in average consumption per customer, and for the sixth successive year 
a drop in average cost per kilowatt-hour. This average cost is now at its lowest 
level since 1952. Industrial power service registered the largest proportional 
increases among the classes of service both in number of customers and in energy 
consumption, and, like residential and commercial service, showed an increase 
in average consumption per customer and a decrease in average cost per 
kilowatt-hour. 



Farm and hamlet service customers in recent years have consistently in- 
creased their annual energy consumption by substantial amounts, the resulting 
increased revenue being reflected in a reduction in the average cost per kilowatt- 
hour for these classes of service. The increase in revenue has, to a large extent, 
offset the rising costs experienced. Summer cottage residents, however, have 
not comparably increased their average energy consumption, so that average 

revenue per customer has not 
grown appreciably over the 
past seven years. To ensure 
that summer service carried 
a more appropriate share of 
the cost of providing service 
the summer service rate struc- 
ture was revised, establishing 
a uniform annual fixed charge 
for all summer services and 
introducing a minimum 
annual energy charge to 
supplement the annual fixed 
charge. The sharp increase 
in summer service revenue in 
1960 is attributable in part to 
this change of rate and in 
part to the net increase of 
3,806 new summer services. 
The small increase in average 
consumption per summer 
service customer indicates 
that customers are beginning 
to take advantage of the 

MODERN ELECTRICAL DAIRY FARMING— The large insulated ., , , ., 

bulk milk cooler is the most prominent item of electric equipment energy provided Under the 

in this dairy farm installation, but the fluorescent lighting and the minimum energV charge in 
electric heater in the upper corner of the room undoubtedly add 

to the feeling of comfort and convenience. the rate Structure. 




Reports from the Regions 



49 




SAVING TIME AND LABOUR ON THE FARM — A barn-cleaning job that would normally require one man for 

2 hours every day is completed in 1 2 minutes by electric machines. To many farmers, the saving in time is 

even more important than the saving in labour. 

Capital Investment 

The net increase in the investment in rural distribution facilities at cost 
was $12,639,561 in 1960, bringing the total investment in rural facilities to 
$266,583,395 at the end of the year. In accordance with the terms of The Rural 
Hydro-Electric Distribution Act passed in 1921, the Government of Ontario 
has materially assisted agriculture in the Province by contributing half the 
capital cost of these rural electric distribution facilities. Up to the end of 1960 
the contribution made under this legislation had amounted to $115,175,265. 



REPORTS FROM THE REGIONS 



Western Region 



The water-heater programs in municipalities in the Western Region resulted 
in the installation of approximately 2,600 heaters. By the end of the year there 
were 88 homes and 34 commercial establishments with electric heating installa- 
tions. In Essex County, interest in supplementary electric heating was stimulated 
by making portable heaters available to customers on a trial basis. In Chatham 
the municipal utility, in co-operation with local appliance dealers, successfully 
carried out a special program for promoting the sale of electric dryers. 

Municipal electrical utilities in the Western Region continued in 1960 to 
improve and extend their distribution facilities to meet steadily increasing 
demands for power. London increased its substation capacity by 4,700 kva and 
inaugurated a program to provide underground distribution in all new subdivi- 
sions. The utility also installed 3 miles of 13.8-kv and 4-kv underground cable 



50 



The Commission's Customers 



mmimi 



ESSEX RURAL AREA OFFICE 

Administrative facilities and other services for the former Essex, Harrow, and Kingsville Rural Operating Areas 
are now combined in this new office. In the well-lighted, electrically heated building of functional design, 
space is also provided for the display of electric equipment for use in the home, and in industry. 



and three transformer vaults in the downtown network. In Chatham a small 
residential underground distribution system was installed and a 3,000-kva 
station was placed in service in the northern residential section of the city. 
In Windsor one 5,000-kva unit of a 10,000-kva station was placed in service in 
the downtown area to provide greater transformer capacity for the increasing load. 
Other new additions were a 5,000-kva station in Riverside, two 3,000-kva stations 
in Sandwich East Township, and one 3,000-kva station in Sandwich West Town- 
ship. 

General improvements to distribution facilities were carried out also in Wood- 
stock and Tillsonburg. A number of the smaller utilities in the Region adopted 
long-range plans for the rehabilitation of their distribution systems. 

With the purchase of a suitable building in the town the Ingersoll Public 
Utilities Commission completed plans for the amalgamation of its office and 
service facilities. 



West Central Region 

In the West Central Region, sales activity was increased during the year 
and water-heater rental programs were instituted in Burford, Plattsville, Port 
Dover, Princeton, St. Mary's, and Seaforth. At the year-end, 31 utilities were 
actively engaged in promoting the installation of electric water-heaters. Elec- 
trically heated houses have been added in the major municipalities and in a 
number of smaller municipalities in the Region. 



Western and West Central Regions 



51 



As a result of annexations, a total of 2,749 rural customers and 66.7 miles of 
distribution lines were transferred to various municipal utilities. 

Several utilities found it necessary to expand their distribution facilities by 
extensions, improvements, and municipal substation construction. The electrical 
utilities in Brantford, Burlington, Dundas, and Hamilton added to their trans- 
formation facilities. In Hagersville, in conjunction with highway widening, the 
distribution system along the main street was completely rebuilt using concrete 
poles. The distribution system in Jarvis was rebuilt for operation at 8 kv. 
Extensions were also carried out in underground distribution systems in the 
downtown sections and residential subdivisions in Brantford, Hamilton, Kit- 
chener, and Waterloo. 

A number of municipalities in the Region modernized their street-lighting 
systems with the installation of fluorescent and mercury-vapour units. In 
Hamilton the second section of the Northeastern Expressway was completed 
with the installation of a complete underground street-lighting distribution 
system and mercury-vapour luminaires on concrete standards. Guelph reached 
the midway point in a six-year program of converting all lighting on residential 
streets to mercury-vapour type. 

Caledonia and Port Rowan completed the construction of new service 
buildings. Brantford Township, Guelph, and Stratford officially opened new 
electrically heated utility offices and service buildings. 




STRATFORD PUBLIC UTILITY COMMISSION OFFICE — For the convenience of customers, service personnel 

are easily accessible at the attractively curved counter in the new utility offices. Executive offices and service 

departments are located behind the main office in the split-level structure. 



52 The Commission's Customers 

Niagara Region 

The steady growth in number of customers and the consequent increase in 
demand for electricity in most utilities in the Region necessitated improvements 
and extensions to the electrical distribution systems. The capacities of sub- 
stations at Merritton and Chippawa were increased and new substations were 
installed in Stamford Township and Niagara Falls. The new substation at 
Niagara Falls is an entirely underground, 13.8/4-kv, 1,500-kva, vault-type 
installation with metalclad switchgear. 

Municipal utilities were quite active in the sales promotion program. Electric 
heating was installed in a number of homes and a variety of commercial establish- 
ments. The promotion of Medallion standards resulted in the completion of 
6 Gold and 27 Bronze Medallion houses during the year. 

Ontario Municipal Board orders were issued late in the year for the amal- 
gamation of the City of St. Catharines with the Towns of Merritton and Port 
Dalhousie and a part of Grantham Township, for the annexation of parts of the 
Townships of Crowland, Humberstone, and Thorold to the City of Welland, and 
for the annexation of part of Grantham Township to Niagara Township. 
The transfer of a large number of customers with relatively high average energy 
consumption from rural service to service by the municipal utilities will result in 
a substantial decrease in the Commission's rural revenue in the rural operating 
areas affected. 



Central Region (formerly Toronto Region) 

Although not quite as rapid as in 1959, growth in population and the use of 
electric energy was significant in the majority of the municipal electrical utilities 
in the Central Region during 1960. To meet the load growth, increased trans- 
formation and distribution facilities were required in Brampton, Etobicoke 
Township, Georgetown, Newcastle, North York Township, Oshawa, Scar- 
borough Township, Toronto, and Toronto Township. A total of 21 new muni- 
cipally owned substations were installed and increases in capacity were made at 
a number of other locations. In addition, there was a significant increase in the 
numbers of new industrial customers and of customer-owned substations. 

By the end of 1960 more than 12,000 customers had been added to the num- 
ber being served in the Region as a whole. 

In built-up municipalities where there are very few new building lots avail- 
able, there is a strong trend toward the construction of large apartment buildings. 

The peak load supplied by Toronto Hydro-Electric System in 1960 was 
615,491 kilowatts, an increase of 83,869 kilowatts, or approximately 4 per cent 
over the load in 1959, and transformer station capacity was increased by 19,450 
kva to take care of these expanding loads. Supervisory control equipment was 
installed in Carlaw Station, thereby completing the program of converting 
system stations to remote-control operation. A total of approximately 13.8 
miles of underground 15-kv power cable was installed, in part for network 



Niagara and Central Regions 



53 



primary feeders, in part to supply system distribution stations and to provide 
13.2-kv power to two new large power customers. In addition, approximately 
51 miles of power cable of lower- voltage and control cables were installed under- 
ground. The underground conduit system in Toronto and Leaside was extended 
by the installation of 17 miles of duct and 10 underground transformer vaults. 
The total length of underground duct owned by Toronto Hydro-Electric System 
at the end of the year exceeded 2,000 miles. 

By an Act of the Provincial Legislature, the Oakville and Trafalgar Public 
Utilities Commissions were amalgamated, effective July 1, 1960. The amalgam- 
ated utilities arranged to purchase the rural facilities located within the extended 
boundaries effective January 1, 1961. 

Etobicoke Township Hydro-Electric Commission opened a new three- 
storey service centre featuring three types of electric heating, a heat pump for 
the control-room, baseboard heaters for offices, and unit resistance heaters for 
the garage and service areas. Newmarket Hydro-Electric Commission completed 
and occupied a new electrically heated office building during 1960, and the Rich- 
mond Hill and Scarborough utilities completed the construction of new elec- 
trically heated garage and storage buildings. 

In Toronto, construction was begun on a $2.5-million service centre. A 
two-storey building with a total floor area of 160,000 square feet will house the 




LAKEVIEW GENERATING STATION 

Left: The biggest steam drum in Canada, 212 tons in weight, was hoisted into place in May 1960. At full 
load the boiler will, per hour, require the consumption of 1 1 tons of coal and produce a maximum of 
2,000,000 pounds of steam. 



Right: This 25-ton super-heater outlet header will be an important link between the boiler and the turbo- 
generator. The tubing, which is made of special heat-resistant alloy steel, will convey steam at a 
pressure of 2,450 pounds per square inch and a temperature of 1,000° Fahrenheit. 



54 The Commission's Customers 

meter and garage departments and a section of the station construction and 
service maintenance departments. Electric heating is being used throughout — 
strip heaters in the garage section and in the offices, fan-type electric heaters in 
the machine shop and electric shop areas, and radiant heating in the garage 
repair areas. The new service centre is scheduled for completion by the summer 
of 1961. 

Following an administrative change effective March 31, 1960, and the 
consequent relocation of the eastern boundary of the Region, the municipalities 
of Ajax, Bowmanville, Newcastle, Orono, Oshawa, Pickering, and Whitby were 
transferred from the East Central to the Central Region. 



Georgian Bay Region 

In order to meet growing power requirements, substation capacity was 
increased in Meaford and Orangeville, and the capacity of the Parry Sound 
municipal substation was enlarged. 

During the year, general retail rate reductions were introduced in Beeton, 
Coldwater, Collingwood, Cookstown, Dundalk, Kirkfield, Ripley, Shelburne, 
Sunderland, and Tottenham. A general increase in retail rates was put into 
effect in Parry Sound. 

The distribution voltage in Cookstown was changed from 4 kv to 8 kv in 
conjunction with increasing the capacity of the local substation from 300 to 
2,000 kva. This station now serves both the municipality and the adjacent 
rural area. 

The City of Barrie is now engaged in replacing all incandescent street-lights 
with fluorescent units. All the new lights, with the exception of those in the 
downtown business section, are expected to be installed by the spring of 1961. 

With the increasing interest in electric heating in the Region, a total of 182 
residences and 45 commercial premises were being heated entirely by electricity 
at the end of the year. A new electrically heated office and storeroom building 
was officially opened by Paisley Hydro-Electric Commission. 



East Central Region 

In the East Central Region the steady growth of municipal loads in 1960 
required additional substation capacity in Belleville, Brighton, Campbellford, 
Cobourg, Deseronto, Marmora, and Norwood. Extensive improvements to the 
electrical distribution systems to meet the growing loads were carried out in 
Bancroft, Bobcaygeon, Havelock, Lakefield, Norwood, and Trenton. Street- 
lighting systems in Bloomfield and Deseronto were modernized with the instal- 
lation of fluorescent lighting units. 

In Bancroft a modern municipal building was completed to provide accom- 
modation for municipal services and for the Public Utilities Commission. In 
Port Hope the municipal utility office was completely renovated, and a heat 
pump was installed for heating and air-conditioning. 



Georgian Bay, East Central, Eastern, and Northeastern Regions 



55 



Eastern Region 

In the Eastern Region a substantial number of extensions and improvements 
to municipal electrical distribution systems included the construction in Brock- 
ville of a 7,500-kva substation, which was placed in service in 1960. This station 
supplies power at 8 kv to serve the rural area recently annexed by this muni- 
cipality. A second stage of the primary underground distribution system in the 
business district of Brockville was completed. The distribution system in 
L'Orignal was changed over to 8-kv operation, thus eliminating the need for 
additional step-down transformation facilities. 

In Ottawa the number 
of customers increased during 
1960 by 3,213, or nearly 4 per 
cent, to a total of 87,629. 
Three new substations with 
a total capacity of 30,000 kva 
were added to the municipal 
system. The underground 
network in the city was ex- 
tended by 11 miles of 12-kv 
and 5-kv underground cable. 
Approximately 7,500 feet of 
duct line were constructed 
and 20,000 kva of transformer 
capacity were installed. 



Improvements to muni- 
cipal distribution systems in 
1960 included the extension 
and modernization of street 
lighting on main thorough- 
fares. A fluorescent street- 
lighting system was installed 
in Alexandria, mercury- 
vapour units were added in 
Chalk River and Peter- 
Ottawa, and in Brockville 31 
wiring in the new subdivision 




NUCLEAR POWER DEMONSTRATION — This is the inside well 

wall of the reactor being installed at the 20,000-kilowatt nuclear 

station, which is scheduled for initial operation in 1961. 

borough, over 600 new street lights were added in 
street-lighting units were served with underground 
of Britannia Heights. 

Water-heater rental and sales programs were 
side, Hawkesbury, Iroquois, and Winchester. In 
to a new electrically heated school. 



instituted in Arnprior, Brae- 
Cobden, service was supplied 



Northeastern Region 

Five municipalities formerly served under fixed-rate contracts became cost- 
contract customers of the Commission during 1960 — Sudbury effective Septem- 
ber 1, Massey and Webbwood effective October 1, and Coniston and W T est 



56 



The Commission's Customers 



Ferris Township effective November 1. Espanola became a municipal customer 
of the Commission on October 1, having acquired a company-owned distribution 
system and installed a 5,000-kva substation. Power was supplied from the new 
Espanola Transformer Station. 

The operations of the Sudbury Hydro-Electric Commission were consider- 
ably expanded following the annexation by the city of McKim Township and 
part of Neelon Township. Sudbury acquired the rural distribution system and 
three substations supplying about 6,000 customers in the suburban area. 

The distribution system in New Liskeard was changed from 2,400-volt 
ungrounded operation to 4, 160- volt grounded operation in order to improve 
customer service. Additional substation capacity was provided to meet increased 
demands for power in Capreol, Englehart, and Kirkland Lake. 

During the year the retail rates in 18 local systems were revised on the basis 
of the new rate structures. Sudbury Hydro-Electric Commission established a 
100-ampere minimum for all new residential services, and opened a sales depart- 
ment to encourage water-heater sales and load building. 



Northwestern Region 

Sales activity in the North- 
western Region produced en- 
couraging response. A two- 
day presentation of "Hydro 
Showtime", sponsored by the 
Fort William Hydro-Electric 
Commission and the Port 
Arthur Public Utilities Com- 
mission at the Lakehead Audi- 
torium, had a record attend- 
ance of 1,550 persons. The 
success of the project is attri- 
butable to the excellent co- 
operation of the utilities, the 
electric appliance distribu- 
tors, and the appliance dealers. 



Fort William Hydro- 
Electric Commission officially 
opened its new office building 
complete with a 25-ton air- 
conditioning unit, and an impressive display of fluorescent lighting. 




THUNDER BAY GENERATING STATION — Work proceeds on the 

installation of the generator for the 1 00,000-kilowatt unit at 

Thunder Bay Generating Station, which is scheduled for service 

late in 1961. 



In order to improve service to customers, the Beardmore local system dis- 
tributing station capacity was increased and the distribution voltage was changed 
from 2,300-volt to 4, 160- volt operation. 

Reductions in retail rates to customers in Dryden and Terrace Bay were 
introduced in 1960. 



Public Relations and Services to Customers 57 

PUBLIC RELATIONS AND SERVICES TO CUSTOMERS 

The Commission continued to follow the practice of the last several years in 
directing public attention to the advantages of using electricity, and displaying 
innovations in equipment, style, and appliance convenience at exhibitions, fairs, 
and conventions of various kinds. Convincing evidence of widespread public 
interest in the variety of service that electricity can provide is given every year 
at such displays as the Hydro exhibit at the Canadian National Exhibition, and 
the exhibit at the International Ploughing Match, held in 1960 near Aylmer, 
Ontario. A cooking school and electric appliance demonstration held in 
conjunction with the Ploughing Match was attended by more than 3,600 people. 
In all, almost 750,000 persons visited Commission displays established at local 
fairs and exhibitions. 

There is a substantial and continuing public interest in the Commission's 
large engineering achievements, and approximately 201,000 visitors availed 
themselves during the year of the opportunity to visit one or more of the large 
generating stations which are open to the public. In recognition of this interest, 
a 30-minute film summarizing activities of the Commission during 1960 was 
prepared for use by schools, service clubs, and other interested groups. A series 
of thirteen 15-minute programs entitled "Men of Power" was prepared by the 
Commission for radio broadcast and it was carried by thirty-seven radio stations 
during 1960. 

Inspection 

The installation of electric equipment and wiring is governed by regulations 
made by the Commission under The Power Commission Act. Members of the 
Commission's staff participate in the administrative and committee activities 
of national code-making bodies and find thereby the opportunity to correlate 
Commission regulations with the latest developments in technology and equip- 
ment recognized by the Canadian Electrical Code. 

In the fulfilment of its responsibilities under The Power Commission Act 
the Commission issues permits covering the installation or renovation of electric 
equipment and through the activity of its inspection staff follows the progress 
of work to completion. The extent of this activity is in some measure an indi- 
cation of the pace of construction work in general. During 1960 a total of 290,406 
permits were issued for electrical installations, and 653,969 inspections were 
made by the Commission's staff. 

On the basis of electrical inspection reports, the number of fatal accidents 
attributable to electrical causes declined from 15 in 1959 to 8 in 1960. The 
number of fires apparently of electrical origin was 29 in 1960 as compared with 
17 in 1959. 

Lighting 

The Academy of Lighting Arts conducted twelve of its courses in various 
centres in the Province during the year, and 263 persons successfully completed 
their training as Residential Lighting Consultants at these sessions. 



58 The Commission's Customers 

In addition to providing guidance on the lighting problems of customers, the 
Commission's specialist staff prepared surveys, plans, and specifications for 
lighting installation in 128 stores, offices, and other commercial establishments, 
and for 67 schools and 14 Medallion Standard houses. 

Service to Industrial Power Customers 

A program of seminar-type instruction is carried out by the Commission in 
order to keep the staffs of industrial customers informed regarding up-to-date 
methods of operating their electric equipment and their plant distribution 
systems so that the most effective use is made of this equipment. 



SECTION IV 



PLANNING, ENGINEERING, AND CONSTRUCTION 



DURING the past decade the capacity of the Commission's thermal-electric 
resources increased from a mere 53,500 kilowatts in 1950 to 995,900 kilowatts 
in 1960. Thermal-electric power now represents 17 per cent of the total capacity 
of the Commission's generating stations. The table on page 60 indicates the 
predominant importance of thermal-electric facilities in the power development 
program in the years immediately ahead, and the increasing significance of 
nuclear-electric facilities in the slightly more distant future. The hydro-electric 
potential of the Province is by no means exhausted, although there are no new 
major sites available for development in the Southern Ontario System. A pro- 
gram is already under way to develop up to 2 million kilowatts at a number of 
sites, chiefly in the Northern Ontario Properties. The part played by the 
hydraulic generating facilities now under consideration, though smaller than that 
of the thermal resources, will be significant in its own way. 

59 



60 



Planning, Engineering, and Construction 



Summary of the Power Development Program 
as at December 31, 1960 



No. of In-service 

System and Development units schedule Capacity* 

kw 
SOUTHERN ONTARIO SYSTEM 

Richard L. Hearn— Toronto 8T 1951—1961 l,200,000t 

Nuclear Power Demonstration — near Des Joachims GS IT 1961 20,000f 

Lakeview— near Toronto 4 T 1961—1964 1 ,200,000f 

Douglas Point Nuclear Power— near Kincardine IT 1964 200,000f 

NORTHERN ONTARIO PROPERTIES 
Northeastern Division 

Red Rock Falls— Mississagi River 2H 1960—1961 40,000 

Otter Rapids— Abitibi River 4H 1961—1963 172,000 

Little Long— Mattagami River 2H 1963 114,000 

Harmon— Mattagami River 3 H 1965 110,000 

Kipling— Mattagami River 3H 1966 132,000 

Northwestern Division 

Thunder Bay— Fort William IT 1961 100,000 1 

*Capacities quoted are dependable at time of system peak except those marked f, which are 
installed capacities. 



Extensions may be made to certain major hydraulic stations already in 
operation. These extensions, however, will be small in relation to the present 
installations and will provide, in the main, only short-time peak capacity. The 
development of certain pumped-storage sites may also provide short-time peak 
power. In northern Ontario the sites which give the best promise as sources of 




POWER DEVELOPMENT IN THE JAMES BAY WATERSHED— At Little Long Rapids, 4 miles up stream from 
Smoky Falls on the Mattagami River, the Commission is building the first of three power developments. 



The Power Development Program 
Expenditures on Capital Construction 1951-1960 



(.1 





Genera- 
tion 


Transfor- 
mation 


Trans- 
mission 


Rural 


Other 


Total 


1951. . 


$'000 
94,267 
96,682 

117,311 
76,649 
68,483 

128,245 

151,738 

126,204 

98,251 

82,506 


$'000 

25,143 

22,954 

21,711 

15,360 

12,624 

13,464 
17,302 
20,688 
20,788 
16,624 


$'000 

17,886 

15,628 

15,444 

16,091 

10,823 

11,424 
19,295 
20,806 
12,159 
12,230 


$'000 

22,725 

23,033 

24,402 

20,133 

18,961 

17,244 
17,347 
19,556 
19,542 
17,687 


$'000 
4,597 
4,534 
4,767 
4,585 
3,681 

2,626 
3,010 
3,402 
3,364 
2,992 


$'000 
164,618 


1952 

1953 


162,831 
183,635 


1954 

1955 

1956 

1957 

1958 

1959 


132,818 
114,572 

173,003 
208,692 
190,656 
154,104 


1960 


132,039 


Total 


1,040,336 


186,658 


151,786 


200,630 


37,558 


1,616,968 







energy, that is, producing power at a continuous rate over extended periods of 
time, are located on the Abitibi and Mattagami Rivers. The present plan is to 
develop them in the near future, and to develop other economic sites to meet 
later system requirements. Some of the sites on the Abitibi and Mattagami 
Rivers can be conveniently developed in two stages. The first involves installa- 
tion of capacities which are about half the ultimate values, but which are never- 
theless capable of generating most of the potential energy of the sites. The 
second stage involves completing their installation at a later date to provide 




OTTER RAPIDS GENERATING STATION— This picture shows progress of construction in June 1960 with the 

headworks for four units well advanced and flow in the western channel passing through the diversion ports. 

In the next stage the eastern channel was cofferdammed to permit completion of the bulkhead section to 

incorporate the sluiceway structure on the east bank in the completed dam. 



62 Planning, Engineering, and Construction 

short-time peaking capacity that will then be required by the system. This 
procedure will properly co-ordinate the development of hydraulic and thermal 
capacity to meet over-all system peak and energy requirements. 

The first stage of development at Otter Rapids Generating Station on the 
Abitibi River was begun in 1958, and the first unit at this station is scheduled 
for initial operation in 1961. The first stage of development at Little Long 
Generating Station on the Mattagami River was begun in 1960. By 1966 the 
first stage at these two sites, and at Harmon and Kipling Generating Stations 
on the Mattagami River, will be in service, providing a total dependable peak 
capacity of 528,000 kilowatts. 

The output of these four stations will be carried over 230-kv lines and pooled 
at Pinard Transformer Station, which is being built near Abitibi Canyon Gener- 
ating Station. From that point a single-circuit, 460-kv transmission line, the 
first major transmission line of 460-kv construction in North America, will 
carry the power to Sudbury. Until approximately 1965 the line will be operated 
at 230 kv. The surplus of this generation over requirements in the North- 
eastern Division will be transmitted to southern Ontario over existing inter- 
connection facilities, augmented by additional transmission, from R. H. Martin- 
dale Transformer Station to Essa Transformer Station. These new facilities 
will be operated initially at 230 kv but will be suitable for future use at 460 kv. 

Other economically feasible hydraulic sites, which together with those 
currently being developed represent the nearly 2 million kilowatts of potential 
capacity, are variously located on the Abitibi, Mattagami, Missinaibi, Mississagi, 
Montreal, and Madawaska Rivers. They have, for the most part, more value as 
short-time peaking resources than as energy producers. 

During 1960 the principal work in the construction of generating facilities 
was carried out at six locations. Two are hydro-electric developments in northern 
Ontario, Red Rock Falls 14 miles northeast of Thessalon on the Mississagi 
River, and Otter Rapids 60 miles northeast of Kapuskasing on the Abitibi 
River. The others are Lakeview and Richard L. Hearn Generating Stations in 
the Toronto area, Thunder Bay Generating Station in Fort William, and the 
Nuclear Power Demonstration plant near Des Joachims Generating Station on 
the Ottawa River. Four other projects recently added to the power development 
program are the Douglas Point Nuclear Power Station, being built for Atomic 
Energy of Canada Limited, and the three hydraulic developments on the Matta- 
gami River already mentioned. 

Survey Work 

The preparation at Head Office of topographic plans for generating facilities 
and other projects involved the extended use of the stereoplotter on photo- 
grammetric surveys for approximately 239,000 acres of ground. Surveys for 
engineering purposes were carried out on approximately 230 miles of transmission 
line right of way, and other surveys were conducted at six power development 
sites. A new hydrostatic level recently developed by Commission engineers 
has been used effectively to mark the limits of clearing for the headpond at Little 



Progress on Power Developments — Southern Ontario System 
Total Mileage of Transmission Lines and Circuits 



63 





Line route or 


Circuit 




structure miles 


mi 


les 


Voltage and Structure 


At Dec. 31, 


At Dec. 31, 


At Dec. 31, 


At Dec. 31, 




1959 


1960 


1959 


1960 


Southern Ontario System 










230,000-volt steel tower 


2,939.27 


2,940.46 


3,780.81 


3,783.41 


115,000-volt steel tower 


1,511.57 


1,515.62 


2,364.80 


2,390.44 


1 15,000-volt wood pole 


952.29 


953.20 


956.90 


957.81 


115,000-volt underground cable 


20.60 


27.22 


45.65 


59.98 


60,000- volt steel tower 


11.17 


11.17 


12.30 


12.30 


60,000- volt wood pole 


3.31 


3.31 


3.31 


3.31 


44, 000- volt and less. wood and steel. . . 


4,778.85 


4,836.24 


5,277.36 


5,330.81 


Total Southern Ontario System .... 


10,217.06 


10,287.22 


12,441.13 


12,538.06 


Northern Ontario Properties 










230,000-volt steel tower 


55.28 


55.28 


55.28 


55.28 


230,000-volt wood pole 


251.80 


251.80 


251.80 


251.80 


115,000-volt steel tower 


894.24 


894.75 


1,531.52 


1,532.33 


1 15,000-volt wood pole 


1,476.46 


1,472.65 


1,476.46 


1,472.65 


69,000-volt wood pole 


203.72 


203.72 


203.72 


203.72 


44,000- volt and less. wood and steel. . . 


1,685.34 


1,708.79 


1,753.40 


1,777.03 


Total Northern Ontario Properties. . 


4,566.84 


4,586.99 


5,272.18 


5,292.81 


Total — All systems 


14,783.90 


14,874.21 


17,713.31 


17,830.87 







Long Generating Station, 
of this type of work. 



This will effect a considerable reduction in the cost 



Office and Service Buildings 

Drawings and specifications for the Commission's new Research Laboratory 
were prepared during the year, and in order to speed construction, separate 
contracts were let for the substructure, structural steel, metallic waterproofing, 
elevators, and superstructure. By the end of 1960 the contracts for the sub- 
structure and structural steel were completed, and work for the superstructure 
was well under way. Design and studies for the high-voltage test laboratory 
to be built adjacent to the Research Laboratory were well advanced and the 
preparation of drawings is to commence early in 1961. 

Area offices were built at Cobourg, Dundas, and Guelph, and combined 
office and service buildings were built at Kenora and Essex. 

SOUTHERN ONTARIO SYSTEM 
Progress on Power Developments 

Construction of generating facilities in the Southern Ontario System was 
confined exclusively to stations which will use either fossil or nuclear fuels. 
Work was rapidly approaching completion at Richard L. Hearn Generating 
Station in Toronto and at the Nuclear Power Demonstration plant near Des 
Joachims Generating Station on the Ottawa River. The first unit at Lakeview 
Generating Station near Toronto is scheduled for service during 1961, and 
Douglas Point Nuclear Power Station, between Kincardine and Port Elgin, 
for service in 1964. 



64 



Planning, Engineering, and Construction 



Richard L. Hearn Generating Station — Toronto 



Location 
Installed Capacity 

In Service 



In-service Schedule 

Estimated Cost 
(Units No. 5, 6, 
7, and 8 only) 



—Eastern area of the Toronto waterfront. 

-1,200,000 kilowatts, 60 cycles (400,000 kilowatts in 4 
units, and 800,000 kilowatts in 4 units). 

-Unit No. 1, 1951; Units No. 2 and 3, 1952; Unit No. 4, 
1953; Unit No. 5, 1959; Unit No. 6 on January 7, 1960; 
Unit No. 7 on September 23, 1960. 

—Unit No. 8 in 1961. 

— $107,700,000, including generation, step-up transforma- 
tion, and high-voltage switching at the site. 



Unit No. 5, which had suffered boiler damage in 1959, was returned to full 
service in June 1960 but was operated as a synchronous condenser for a large 
part of the year. Unit No. 6 was operated as a generator for the first four months 
of the year and subsequently also as a synchronous condenser. Unit No. 7 was 
operated for some weeks after the in-service date shown but operational difficul- 
ties prevented its being available at the time of the system peak in December. 
It is therefore not included in the figures on dependable peak capacity. Unit No. 
8 is expected to be in service in March 1961. 



Lakeview Generating Station — near Toronto 



Location 

Installed Capacity 
In-service Schedule 

Estimated Cost 



— On Lake Ontario just west of Toronto. 

— 1,200,000 kilowatts in 4 units, 60 cycles. 

-Unit No. 1 in 1961, Unit No. 2 in 1962, Unit No. 3 in 1963, 
and Unit No. 4 in 1964. 

— $167,900,000, including generation, step-up transforma- 
tion, and high-voltage switching at the site. 



The present program of construction at this station includes four 300,000- 
kilowatt units so that the total installed capacity at the end of 1964 will be 
1,200,000 kilowatts. Eventually consideration will be given to the extension of 
the station by two additional units of similar size. The site itself is capable of 
providing for an ultimate capacity of 2,400,000 kilowatts. 

During 1960 the powerhouse building for Units No. 1 and 2 was completed, 
and work was well advanced on the installation of the boiler and turbo-generator 
for Unit No. 1 together with its auxiliary equipment. The 493-foot chimney for 
the first two units towers above the powerhouse structure, which itself is equiva- 
lent in height to a 20-storey building. The extensive cooling-water system for the 
turbo-generators was approaching completion at the end of the year and much 
of the structural steel for coal-handling equipment was in place. The concrete 
dock, now complete, will permit the largest coal-carrying vessels to unload, and 



Thermal-electric and Nuclear -electric Stations 65 

the coal-handling installations will eventually be capable of moving four thousand 
tons an hour from vessel to coal-pile, and two thousand tons an hour from coal- 
pile to bunkers. 

Nuclear Power Demonstration — Ottawa River 

Location — About 2 miles down stream from Des Joachims Generat- 

ing Station. 

Installed Capacity — 20,000 kilowatts in 1 unit, 60 cycles. 

In-service Schedule — 1961. 

Estimated Cost —$32,000,000, to be shared by The Hydro-Electric Power 

Commission of Ontario, Atomic Energy of Canada 
Limited, and Canadian General Electric Company 
Limited. 

At the end of 1960 the installation of equipment in the conventional part 
of the generating station was almost complete and some of the minor auxiliary 
systems were in operating condition. The operating staff moved into the ad- 
ministration sector about the middle of the year. All normal building services 
are now supplied over the permanent connection with the power system. 

The station is expected to be in service late in 1961. 

Douglas Point Nuclear Power Station 

Location — On the shore of Lake Huron between Kincardine and 

Port Elgin. 
Installed Capacity — 200,000 kilowatts in 1 unit, 60 cycles. 
In-service Schedule —1964. 
Estimated Cost —$81,500,000. 

The Commission is participating, together with Atomic Energy of Canada 
Limited, in this project, the first full-scale nuclear power development in Canada. 
It will use natural uranium as a fuel, and heavy water as a moderator in the 
reactor. The name CANDU by which the project was originally known was 
intended to suggest these features of its operation, features in which the whole 
world is continuing to show lively interest. 

The Commission, under its agreement with Atomic Energy of Canada 
Limited, has provided a 2,300-acre site for the station, will build a transmission 
line linking the station with the Southern Ontario System network, will operate 
the station during its trial period, and will purchase the station when its operat- 
ing characteristics have been proved satisfactory. The purchase price will be 
negotiated at a level that will permit the output of the Douglas Point station 
to be competitive with that of a modern coal-fired station of similar size. An 
operating and maintenance staff, trained at the Commission's expense, will be 
ready to assume responsibility when the station is placed in service in 1964. 
Meanwhile the services of the Commission's organization have been made 
available at cost to Atomic Energy of Canada Limited to assist in the design 
and construction of the station. 



66 Planning, Engineering, and Construction 

Additional Equipment at Sir Adam Beck-Niagara Generating Stations 

At Sir Adam Beck-Niagara Generating Station No. 2 a 400,000-kva 
voltage-regulating transformer was placed in service on the 230-kv tie-line to the 
Packard Transformer Station of the Niagara Mohawk Power Corporation. 
A similar unit, scheduled for service in December 1961, is to be installed for the 
230-kv tie-line with the Robert Moses Niagara Generating Station of the Power 
Authority of the State of New York. 

The interchange capability of the residual 25-cycle network in the Niagara 
area and the 60-cycle network was increased and security was improved with the 
placing in service at Sir Adam Beck-Niagara Generating Station No. 1 of the 
45,000-kva, 25/60-cycle frequency-changer formerly used at Chats Falls 
Generating Station. 

Transformer Stations 

Additions to transformer capacity in the Southern Ontario System were 
for the most part consolidations of the major changes that have taken place in 
the System over the past five years. The expenditure for new and improved 
transformation facilities includes construction work for three new 230-kv 
stations and eight new 115-kv stations and substantial increases in capacity at 
several stations both on the 230-kv and on the 115-kv network. 

Stations in the Western, West Central, and Niagara Regions 

At Burlington Transformer Station, preparation for the replacement of the 
230-kv oil circuit-breakers was completed with the installation at the station 
of eight 230-kv air-blast circuit-breakers, each with a rupturing capacity of 
20 million kva. In the Hamilton area the capacity of Hamilton-Gage Trans- 
former Station was increased by the addition of a third 56,000-kva, 115 — 
13.8-kv transformer. A fourth is being installed for service in 1961. At Hamilton- 
Kenilworth Transformer Station one 25,000-kva transformer and two 31,000-kva 
transformers were replaced by two 66,666-kva, 115 — 13.8-kv transformers. 
The capacity of Brantford Transformer Station will be more than doubled with 
the completion of present plans to replace the two 25,000-kva, 115 — 27.6-kv 
transformers with two 83,333-kva units. In order to meet increased loads in the 
Windsor area, the capacity of Windsor-Crawford Transformer Station is being 
increased by the addition of two 83,333-kva, 115 — 27.6-kv transformers which are 
scheduled for service in April 1961. To supply growing loads in the London 
area, the capacity of London-Nelson Transformer Station was doubled by the 
addition of two 33,333-kva, 115 — 13.8-kv transformers. A site was purchased, 
and design work is proceeding for a new 115 — 27.6-kv transformer station near 
Elmira in the West Central Region. It is scheduled for service in October 1961 
with a capacity of 27,000 kva. In the southwestern area of the Region, Seaforth 
and Stratford Transformer Stations were raised from capacities of under 20,000 
kva to capacities of 83,333 kva by the substitution of two 41,666-kva, 115 — 
27.6-kv units for smaller units at each station. 

At Niagara Parks Transformer Station in Niagara Falls, three single-phase, 
25,000-kva transformers and a 75,000-kva regulating transformer were installed 
for the 115 — 69-kv interconnection with the Niagara Mohawk Power Corpora- 
tion. 



Transformer Stations — Southern Ontario System 67 

Stations in the Central Region 

The 230-kv network in the Central Region is being expanded by the addition 
of two transformer stations, Cooksville Transformer Station and Toronto- 
Sheppard Transformer Station, each with an initial capacity of 166,000 kva. 
Each station will have two 83,333-kva, 230 — 27.6-kv transformers, with a further 
provision for four additional and similar units at Cooksville Transformer Station 
and six additional at Toronto-Sheppard Transformer Station. The first will 
relieve the load on A. W. Manby Transformer Station and the second, serving 
parts of Scarborough and Pickering Townships, will relieve the load on Scar- 
borough Transformer Station. At A. W. Manby Transformer Station the 
fourth 215,000-kva, 230 — 115 — 13.8-kv autotransformer was placed in service 
during 1960 and two 115,000-kva, 230 — 115 — 13.8-kv units were released for use 
at Hanover Transformer Station. Line positions are being prepared for two 
230-kv circuits from Lakeview Generating Station. Engineering is under way 
for the addition of two 83,333-kva, 230 — 27.6-kv transformers to meet increased 
27.6-kv demands in the area. At Richview Transformer Station the first of a 
new type of 230-kv oil circuit-breaker with a rupturing capacity of 20 million 
kva was installed. It is the first of eleven such breakers intended to replace the 
present breakers of 10-million-kva rupturing capacity. 

Two 115-kv transformer stations are being built in the Central Region. 
Buttonville Transformer Station will have two 83,333-kva units and supply 
27-kv power to areas at present served by Toronto-Bathurst and Scarborough 
Transformer Stations; Toronto- Runnymede Transformer Station, when it is 
placed in service in mid-1961, will have two similar units and will supply 27-kv 
power in parts of York, North York, and Etobicoke Townships. The ultimate 
installation is planned to include four units at each station. During 1960, 
improvements in capacity were introduced at Toronto-Fairbank and Toronto- 
Teraulay Transformer Stations, circuit-breakers with higher rupturing capacity 
were installed in Toronto- Wiltshire Transformer Station, terminal facilities were 
installed at Toronto-Main Transformer Station for 115-kv underground circuits 
from Richard L. Hearn Generating Station, and switching and bus changes were 
made for the same purpose at Toronto-Strachan and Toronto-Esplanade Trans- 
former Stations. Additional reactive power was made available when the two 
28,000-kva, 13.8-kv, 25/60-cycle frequency-changers at Scarborough Trans- 
former Station were rebuilt and reconnected as four synchronous condensers. 



Stations in the Georgian Bay Region 

In conjunction with the program for the development of power at Douglas 
Point Nuclear Power Station, significant changes are under way for transformer 
facilities in the area. Construction will begin early in 1961 for the installation of 
two 115,000-kva, 230 — 115-kv autotransformers at Hanover Transformer 
Station. A site for a 230-kv switching station west of Orangeville was purchased 
and the double-circuit line between Essa Transformer Station and Detweiler 
Transformer Station will be tapped at this point in 1961 to supply power at 
230 kv to Hanover Transformer Station. 



68 Planning, Engineering, and Construction 

Stations in the East Central and Eastern Regions 

The 230-kv facilities in the Ottawa area were expanded by the installation 
of two 225,000-kva, 230 — 115 — 13.8-kv autotransformers at Hawthorne Trans- 
former Station. Increased 1 15-kv capacity will be provided at Slater Transformer 
Station where the installation of a 66,666-kva, 115 — 12-kv transformer will 
double the station capacity. Further additions are planned for National 
Research Transformer Station, and also for Overbrook Transformer Station 
where the capacity will be doubled by the installation of a 66,666-kva, 115— 
12-kv transformer. Two new 1 15-kv stations, South Gloucester and Manordale 
Distributing Stations, were established to serve 8-kv rural loads in the vicinity 
of Ottawa. Three 20,000-kva regulating transformers were installed at Ottawa 
Transformer Station and at Riverdale Transformer Station to serve 12-kv loads. 

At Ross L. Dobbin Transformer Station, growing 44-kv loads required the 
installation of two 83,333-kva, 230 — 44-kv units, which doubled the 44-kv 
capacity of the station. The two 70,000-kva units at the station, which formerly 
stepped power down in the first of two stages from 230 to 115 to 44 kv, are now 
used to supply only the 1 15-kv network,! thus raising 1 15-kv capacity at the 
station from 90,000 kva to 140,000 kva. 



Transmission Lines 

With the approaching completion of the expansion at Richard L. Hearn 
Generating Station and the incorporation of its increased output into the power 
system, the underground facilities in the Toronto area were extended by more 
than 14 circuit miles of 1 15-kv cable. An additional 0.8 circuit mile of under- 
ground cable for 230-kv operation is under construction for incorporating Lake- 
view Generating Station into the power system in 1961. Just over 1 mile of 
single-circuit, 1 15-kv cable was installed in a pipe available between Don Fleet 
Junction and Toronto-Esplanade Transformer Station. This section, a high- 
pressure gas, pipe-type installation, marked the first time the Commission has 
used a polyethylene sheath type of cable. The other sections installed during 
1960 were oil-filled, direct-buried cable sheathed in lead. 

Line rearrangements were carried out for 230-kv and 1 15-kv overhead 
facilities at six stations in the Toronto area. Over 5 miles of double-circuit, 
230-kv line will be strung on bridge-type towers now under construction between 
Lakeview Generating Station and A. W. Manby Transformer Station. One 
extensive addition to the 230-kv network was nearly complete at the end of 1960, 
the double-circuit steel-tower line extending from Neale Junction near Hamilton 
to E. V. Buchanan Transformer Station near London and involving nearly 
66 miles of line construction. From Mount Hope Junction westward the line 
roughly parallels the 230-kv, single-circuit line built in 1948. The new line uses 
aluminum, steel-reinforced conductors and galvanized steel for the overhead 
ground cables. It is the first high-voltage line built by the Commission in 
recent years using toughened glass insulators. 

As part of the eventual plan to bring power from the Douglas Point Nuclear 
Power Station into the Southern Ontario System, and partly to improve service 



Progress on Power Developments — Northern Ontario Properties 69 

in the Orangeville-Hanover area, the Commission is building a 230-kv, double- 
circuit, steel-tower line to Hanover from a point near Orangeville on the Essa 
Transformer Station to Detweiler Transformer Station line. It will be strung 
with aluminum, steel-reinforced conductors. The aluminum, steel-reinforced, 
overhead ground cables being used on this line have a much longer service life 
than conventional galvanized steel ground cable and their use on this line is 
an innovation in the Commission's transmission line design. 

NORTHERN ONTARIO PROPERTIES 

Progress on Power Developments 

Brief progress reports are given in the following paragraphs on construction 
at Thunder Bay Generating Station in Fort William, at Otter Rapids Generating 
Station on the Abitibi River, and at the three Mattagami River stations, Little 
Long, Harmon, and Kipling Generating Stations. A more complete description 
is given for Red Rock Falls Generating Station, which was placed in service in 
November 1960. 

Thunder Bay Generating Station — Fort William 

Location —North shore of the Mission River in Fort William. 

Installed Capacity — 100,000 kilowatts in 1 unit, 60 cycles. 
In-service Schedule — 1961. 

Estimated Cost — $26,000,000, including generation, step-up transformation, 

and high-voltage switching at the site. 

During 1960 the main work related to site and buildings was brought close 
to completion. The installation of window glass for the powerhouse, and con- 
struction work for the administrative building and certain smaller structures 
remained to be done. 

The boiler and turbo-generator are being installed, and both the high- 
pressure and the low-pressure piping is being erected. The switchyard structures 
and the main transformer are already in place. 

Present schedules indicate that the unit will be tested for service towards 
the end of 1961. 

Otter Rapids Generating Station — Abitibi River 

Location — 60 miles northeast of Kapuskasing and 23 miles down 

stream from Abitibi Canyon Generating Station. 

Dependable Peak 

Capacity — 172,000 kilowatts in 4 units, 60 cycles. 

Rated Head —107 feet. 

In-service Schedule — Two units in 1961 and two units in 1963. 

Estimated Cost — $39,100,000, including generation, step-up transformation, 

and high-voltage switching at the site. 

Clearing of the headpond area was almost finished by the end of 1960. 



70 



Planning, Engineering, and Construction 




~. 



OTTER RAPIDS GENERATING STATION — Carefully graded granular material is placed and compacted for 
one of the earth wing-dams. In the background the gantry-crane is placing a sluiceway gate in position. 

As the 1959 Report indicated, the station is being built for a four-unit 
installation but the necessary minimum provision is being made at this stage 
for the possible later addition of four more units. The headworks structure for 
the first four units was almost finished, and the headworks gantry-crane was in 
operation at the end of the year. The four draft-tubes were concreted, two of 
the steel penstocks were in place, and the remaining two were being erected. 
The powerhouse superstructure was closed in and the powerhouse cranes were 
in operation. The headworks structure for two of the additional units was 
built and concreting for the other two was under way. 

The erection bay was built, sluicegates and hoists had been installed in all 
ten control sluices, and construction of wing-dams was finished. 



Little Long Generating Station — Mattagami River 

Location — About 42 miles north of Kapuskasing, about 4 miles up 

stream from Smoky Falls. 
Dependable Peak 

Capacity —114,000 kilowatts in 2 units, 60 cycles. 

Rated Head —91 feet. 

In-service Schedule — -1963. 

Estimated Cost — $53,800,000, including generation, step-up transformation 

and high-voltage switching at the site. 



Mattagami River Developments 



71 



Access to the site 
is by rail from Kapus- 
kasing via the Spruce 
Falls Power and Paper 
Company Railroad to 
Smoky Falls and a 2- 
mile railway spur con- 
structed in 1960. The 
necessary local construc- 
tion roads were almost 
completed. The perma- 
nent camp for housing 
and providing for the 
employees was estab- 
lished. 

Clearing of the 
12,400-acre headpond is 
under way, full advan- 
tage being taken of 
winter ground con- 
ditions. The Commission began by clearing 900 acres by slashing, but is now 
using a diesel-electric machine that has demonstrated its ability to clear wooded 
areas at a rate of 100 acres per week. Greater speed and efficiency may come 
with growing experience. The entire area is scheduled to be cleared in 1962. 




TREE CRUSHER AT WORK— Something of the power of this diesel-electric- 
powered tree crusher can be gauged from the size of the trees being 
felled in its path. In the area being cleared for the headpond at Little 
Long Rapids, the unit is capable of levelling a 20-foot swath through 
heavily wooded land at a speed of 1.5 miles per hour. 



' ' . , : f 



■/.■:: -.■..,- 




LITTLE LONG GENERATING STATION — A 622-foot-long Bailey bridge spans the Mattagami River down 
stream from the site of the main dam, providing an important link in the access road to the powerhouse from 

the nearest railway. 



72 Planning, Engineering, and Construction 

Detailed design of the generating station structures is now under way, and 
construction will be carried out by the Commission's Construction Division. 

The ground in the area of the project is generally flat and poorly drained, 
consisting mainly of muskeg to a maximum depth of 10 feet with a few outcrop- 
pings of rock along the river. As a result, approximately 5 miles of dike with a 
maximum height of 60 feet will be required to contain the headpond. The dikes 
will be built by private contractors. 

Harmon Generating Station (Dependable peak capacity 110,000 kilowatts 

in 3 units) 
and 

Kipling Generating Station (Dependable peak capacity 132,000 kilowatts 

in 3 units) 

These two stations will be located, like Little Long Generating Station, on 
the Mattagami River, but, unlike Little Long Generating Station, they are 
down stream from Smoky Falls. Consideration is being given to the possibility, 
as at Little Long Generating Station, of providing in the initial installations for 
the eventual addition of further units at a later date. 

Field investigations at the Harmon site were completed and preliminary 
engineering for a scheme of development is under way. Engineering studies are 
still proceeding for the Kipling site. Harmon and Kipling Generating Stations 
are scheduled for service in 1965 and 1966 respectively. 

Red Rock Falls Generating Station — Mississagi River 

Location —14 miles northeast of Thessalon and 15 miles down stream 

from George W. Rayner Generating Station. 
Dependable Peak 

Capacity — 40,000 kilowatts in 2 units, 60 cycles. 

Rated Head —93 feet. 

In Service — Unit No. 1 on November 5, 1960. 

In-service Schedule — Unit No. 2 in 1961. 

Estimated Cost . — $19,100,000, including generation, step-up transformation, 

and high-voltage switching at the site. 

The watershed of the Mississagi River covers an area of 3,700 square miles, 
for the most part within the limits of the Mississagi Provincial Forest in the 
Districts of Algoma and Sudbury. Between its origin in Bark Lake in the 
east central sector of the watershed and its outflow into Lake Huron, the Missis- 
sagi River falls approximately 940 feet. Its main tributary streams are the 
Aubinadong and the Wenebegon Rivers in the northern sector and the Little 
White River in the southeastern sector. The rivers flow through gravel-strewn 
gullies between precipitous hills of glacial origin to within 15 miles of the outlet 
of the Mississagi River where the terrain is chiefly alluvial with rock out- 
croppings. Of the four potential sites on the river, Red Rock Falls is the second 
to be developed, the first being the site for George W. Rayner Generating Station 



Red Rock Falls Generating Station 



73 




RED ROCK FALLS GENERATING STATION — At this stage of construction in October 1960 the powerhouse 
structure was complete. In the foreground is the tailrace area, and beyond the protecting cofferdam the 
water rushes through the completed sluiceway structure. The first unit was placed in service in November 1960. 

which is 15 miles up stream. Together the two stations take advantage of 308 
feet of the 698-foot difference in level between the outlet of Rocky Island Lake, 
the principal storage area, and the tailrace level at Red Rock Falls. The mean 
available flow at George W. Rayner Generating Station of just over 3,000 cfs 
is augmented at Red Rock Falls by nearly 1,000 cfs from the Little White River. 

The site selected provides the most economic development of the available 
water, combined with acceptable headpond flooding. Only one small block dam 
was required in addition to the power dam to establish the headpond at the 
685-foot level. By lowering the natural tailrace level from 605 feet to 592 feet 
it was possible to obtain a design head of 93 feet at the station. 



General Description 

The 952-foot concrete power dam for the 2-unit station has a conventional 
headworks, seven 18-foot sluices, and a log-chute. A concrete gravity dam 
separates the headworks from the sluiceway section, and concrete gravity dams 
tie both ends of the main structure into the river banks. The log-chute is in the 
section connecting the headworks with the east bank. 

Headworks 

In the conventional headworks the two power intakes have twin inlets, each 
equipped with a power-operated headgate, trash racks, and provision for the 
later insertion of service gates. Electric hoists mounted directly above each gate 



74 



Planning, Engineering, and Construction 



and protected from the weather by aluminum housings raise and lower the head- 
gates. An electric gantry-type travelling crane running on tracks provides 
hoisting service along the full length of the power dam. 

A steel penstock, 17 feet in diameter and encased in concrete, conveys the 
flow to each scroll-case. Improvement in welding techniques permitted, for the 
hrst time, complete welding of the two scroll-cases in the field. The one-piece, 
cast-steel stay-ring was machined in the shop of the manufacturer and shipped 
to the site together with the preformed plates for the casing. When assembled in 
position, the plates were welded into a single casing and this in turn was welded 
to the stay-ring. Elbow-type draft-tubes carry the discharge to the tailrace 
through two outlets, each divided by a centre pier. The main and centre piers 
support the tailrace deck at the level of the generator floor. An electric gantry- 
type travelling crane runs on tracks on the tailrace deck to provide hoisting 
service for the draft-tube service gates. 

Superstructure 

The unit and the erection bay areas are enclosed by walls of insulated 
aluminum panels on a rigid steel frame 147 feet long by 55 feet wide, the rails of 
the 80-ton overhead service crane being supported by the superstructure columns 
21 feet above floor level. 

Construction Procedure 

Approximately 1,500 acres of wooded land lay between the original river 
channel and the 685-foot contour of regulated high-water level. By agreement, 
the Department of Lands and Forests of Ontario arranged through its District 
Forester for the salvage of as much of the forest cover as was salable, this being 




RED ROCK FALLS GENERATING STATION — The log-chute at Red Rock Falls Generating Station in August 

1960 prior to its incorporation in the wing-dam at the eastern end of the power dam. The cofferdam encloses 

the area for the second stage of construction, which began in May 1959. 



Red Rock Falls Generating Station 



75 



for the most part yellow birch and hard maple. The remainder was cleared by 
persons working in small areas under contract with the Commission. 

Cofferdamming of the construction site was carried out in two stages, the 
first involving the eastern part of the river channel and the second, the western 
part, with provision being made in each stage for adequate stream-flow for log 
driving throughout the period of construction. In the dry area behind the first- 
stage cofferdams, the powerhouse, the eastern section of the power dam, and five 
of the seven sluices were built. One of these five sluices was temporarily left 
without a rollway. During the second stage of construction it was used for log 
driving, and regulation of flow to maintain optimum driving conditions was 
achieved by the use of control gates in diversion ports established in the rollways 
of two other sluices in this section. 

In the second stage of construction the two remaining sluices were built 
behind a cofferdam in the western channel following the removal of part of the 
first cofferdam, and the diversion of the river-flow through the prepared sluice- 
ways. The rollway in the open sluiceway was completed and the diversion ports 
were filled with concrete while the headpond was being raised. 



Main Station Equipment 

The two turbines installed at Red Rock Falls were manufactured by Do- 
minion Engineering Company Limited and are of the fixed-blade propeller type, 




RED ROCK FALLS GENERATING STATION — Only the exciters of the two 20,000-kilowatt units are visible above 
the housings in the generator room. The station is remotely controlled from George W. Rayner Generating 

Station, 1 5 miles up stream. 



76 



Planning, Engineering, and Construction 



rated at 26,500 bhp. The decision to use this type of turbine was based on the 
evidence of numerous model tests, extensive analysis of the problems involved, 
and the successful performance of fixed-blade propeller units at Robert H. 
Saunders-St. Lawrence Generating Station. New designs developed for such 
units during the past decade give promise of good performance and resistance to 
cavitation at rated heads almost 50 per cent greater than those considered the 
maximum for this type of turbine ten years ago. In addition to the mechanical 
advantages ottered by the simplified fixed blades, these turbines have the merit 
of requiring less maintenance time and expense than other types, and of permit- 
ting a reduction in the cost of the associated generators. 

For the first time at any of its generating stations the Commission installed 
the new-type electrohydraulic governors at Red Rock Falls. The electro- 
hydraulic governor, in contrast with conventional mechanical governors, offers 
ease of adjustment for optimum settings, especially for units and stations under 
automatic frequency control. Joint control of several units and stations is also 
more dependable. Experience with the installation at Red Rock Falls Generating 
Station will have a bearing on the decision regarding the advisability of installing 
similar governors at Otter Rapids, Little Long, Harmon, and Kipling Generating 
Stations. 



Electrical Equipment 

The two 13.8-kv, 60-cycle generators manufactured by Canadian General 
Electric Company Limited are rated at 22,500 kva, 0.90 power factor, and operate 
at 1X0 rpm. Each generator is totally enclosed by a concrete and steel housing 

and is cooled by four air-to- 
water heat exchangers. The 
direct-connected exciter is also 
totally enclosed and is cooled 
by air circulated through the 
main heat exchangers. 

Step-up transformation 
to 115 kv is provided by two 
oil-immersed, forced-air- 
cooled transformers operating 
in parallel. The low-voltage 
windings are connected to the 
switchgear bus by pneumatic- 
ally operated disconnect 
switches, and the high-voltage 
windings to the 115-kv bus 
by motor-operated airbreak 
switches. The 115-kv bus is 
tapped into the 115-kv line from George W. Rayner Generating Station to 
Blind River Transformer Station with line-isolating switches on either side of 




RED ROCK FALLS GENERATING STATION The stator for one of 
the two units is shown in the process of being installed. 



Transformer Stations and Transmission Lines — Northern Ontario Properties 77 

the tap. Since no 115-kv breakers are installed, power-line carrier transferred- 
trip equipment is used to trip remote breakers for faults in the main transformer 
or the low-voltage switchgear. 

The station is remotely controlled from George W. Rayner Generating 
Station where unit automatic equipment and supervisory control equipment 
operating over power-line carrier channels are installed. The equipment pro- 
vides for control of a maximum of forty remote operations. In all, 104 annun- 
ciation points, of which 90 are now in use, indicate such occurrences as relay 
operations, excessive temperatures, and low oil-levels. 



Transformer Stations and Transmission Lines 



A new 15,000-kva, 115 — 44-kv station was placed in service at Espanola to 
supply customers in the town and in rural areas, and to provide improved service 
to residents on Manitoulin Island. Work was begun to clear the site near Abitibi 
Canyon Generating Station for Pinard Transformer Station, which will be the 
gathering point for 230-kv power transmitted from new generating facilities on the 
Abitibi and Mattagami Rivers 
in the James Bay watershed. 
At Dryden Transformer Sta- 
tion, two 8,000-kva, 115— 
44 — 4.2-kv transformers were 
replaced by two 15,000-kva 
units to meet increased in- 
dustrial requirements. 

Arrangements have been 
completed for approximately 
5 miles of right of way to 
accommodate two 1 15-kv lines 
which will incorporate power 
from Thunder Bay Generating 
Station into the svstem. 




Surveying for the 460-kv 
line route from Pinard Trans- 
former Station to the vicinity 
of Sudbury, a distance of 
228 miles, was completed. 
The proposed designs sub- 
mitted by tendering companies for 100 suspension structures to be installed 
on the first 30-mile section included guyed aluminum, guyed steel, tubular steel, 
and laminated-wood structures, as well as conventional self-supporting steel 



One of the Commission's photogrammetrists takes a reading on a 
surveying altimeter. This information can be used in conjunction 
with other data in computing elevations. Survey crews mapping 
the Little Long Rapids area in northeastern Ontario were able to 
cover approximately 20 locations per day by helicopter as com- 
pared with about 4 per day by other methods. 



78 



Planning, Engineering, and Construction 



towers. The selection of suspension 
hardware and the establishment 
of spacer and damper requirements 
for the line will be based on con- 
ductor vibration studies carried 
out on a 1-mile test line especially 
erected for the purpose at Port 
Credit. Two phases of 4-conductor 
bundles were used in the test. At 
the Coldwater extra-high-voltage 
test project, corona and radio 
interference tests were continued 
on bundle conductors. 

In order to overcome costly 
problems in tower foundation con- 
struction in the muskeg country 
through which the 460-kv line 
passes, the Commission has evolved 
a new technique. Expansion 
anchors of the type normally used 
on low-voltage lines are installed 
to normal depth in the soil under- 
lying the muskeg, and are back- 
filled with mechanically tamped 
crushed stone. The usual uplift 
movement which occurs when load 
is applied, though permissible for 
guyed wood poles, was not con- 
sidered tolerable for tower foundations. This uplift can be overcome, however, by 
mechanically pre-loading the expansion-type anchors to the required holding 
capacity. When released from this initial load, the anchors are sufficiently firm 
to withstand reloading through the design range with virtually no movement. 




A model of a guyed aluminum transmission tower. One 
hundred towers of this unusual design have been ordered 
for erection on a section of the 460-kv transmission line in 
the muskeg country north of Timmins. 



SECTION V 



RESEARCH AND TESTING ACTIVITIES 



v I ^HE research laboratories of the Commission are staffed and equipped to 
-■- assist all Divisions of the Commission's organization by providing technical 
information as required in the work of design and construction, in the performance 
of tasks for the operation and maintenance of facilities, and in the establishment 
of standard specifications. The primary objective, whether in the laboratory or 
in the field, is the attainment of maximum economy consistent with sound engin- 
eering and efficient operation. 

Effort is steadily directed towards achieving technical advances in the field 
of electric power. Continuous study of the relevant technical literature as 
well as staff participation in the work of various technical bodies keep the Com- 
mission fully informed of progress made elsewhere, and provide the basis for 
many important engineering decisions. 

79 



80 



Research and Testing Activities 



Aids to Design and Construction 



Extra-high-voltage Transmission 

At the Coldwater test station, preliminary investigations were completed 
on levels of corona loss and radio interference on 4-conductor-bundle transmission 
lines. These investigations will facilitate selection of conductor size for the 

extra-high voltage lines north 
of Sudbury. One of the test 
lines was subsequently changed 
to 3-conductor bundles to pro- 
vide data required for the plan- 
ning of the extra-high-voltage 
line south of Sudbury. Other in- 
vestigations were carried out on 
line and insulator hardware. 
For the first time methods were 
devised for relating line corona 
loss to actual precipitation so 
that losses for any annual pre- 
cipitation can now be deter- 
mined. Interpretation of the 
radio interference data obtained 
indicates that conductors of a 
given size can be operated at 
voltages 20 per cent higher than 
those previously considered to 
be the tolerable maxima, without 
exceeding acceptable radio-inter- 
ference levels. 




This lineman at the Coldwater test centre is using one of 

the 1 6-foot line maintenance tools specially developed for 

use at extra-high voltages. The four conductors in the 

foreground are carrying electricity at 460,000 volts. 



Field and laboratory inves- 
tigations explored the mechan- 
ical behaviour of extra-high- 
voltage transmission line equip- 
ped with 4-conductor bundles. Further, by the use of an analogue computer 
and other means, extensive study was given to overvoltages produced in extra- 
high-voltage systems by lightning and by internal causes, and to the performance 
characteristics of extra-high-voltage switchgear and protective devices. 

Power-line Carrier 

Studies related to the use of power-line carrier channels for telemetering 
and load control included problems of excessive noise and of attenuated signals 
on long 230-kv lines, the feasibility of amplifying the carrier signal at intermediate 
points, and the interference caused to other wire services by the carrier signals. 

Distribution-cable Joints and Terminations 

With the development of novel cable joints and terminations making use of 
epoxy resins and other plastics, economies can be achieved in underground instal- 
lations. Less labour and skill are required for the installation of these joints and 



Aids to Design and Construction 



81 



terminations than for those of conventional design. Samples were unimpaired 
after prolonged tests at full cable current and twice the design voltage while 
immersed in water subjected to 6-hour cycles of temperature. 

Effects of Artificial Cooling on Lead Cable Sheath 

A more efficient and economical cooling arrangement for underground cable 
systems has been proposed as an improvement upon the arrangement of poly- 
ethylene pipes installed on a 115-kv cable circuit in Toronto. The proposal 
recommends the enclosure of the three cables of a circuit in a single water- 
carrying pipe. The possibility of fatigue failure of the cable sheath required 
study since temperature changes greater than those commonly experienced 
were expected for the proposed cable system, and fatigue failures have resulted 
from strains induced even by normal daily load variations. Test results indicate 
that sheath shear strains for a given peak conductor temperature in such a 
system are thirty times those in 

a naturally cooled ducted system, "■* 

but that they are still less than 
half the lowest value of strain 
considered as likely to cause failure. 
Further study is required of the 
fatigue properties of lead, lead 
alloys, and other sheath materials, 
particularly of the newer alloys. 

Conductor-vibration Recorder 

With a view to obtaining con- 
ductor-vibration data from lines 
in service rather than from ener- 
gized test spans, a protective live- 
line vibration recorder was de- 
veloped. Powered by small bat- 
teries, and attachable to conduc- 
tors by the use of live-line tools, 
it can record at half-hour intervals 
over a 10-day period the amplitude 
and frequency of vibration close to 
and relative to the conductor 
clamp. 

Concreting Practices 

At Otter Rapids, modifica- 
tions in concrete-dam construction practices were adopted, including the use 
of low for high lifts. This permitted the use of concrete of low-cement content 
and lower than usual slump. Water-reducing admixtures were added and 
fly ash was substituted for cement with a resulting lower temperature rise in 
the concrete. The replacement of more than 150,000 bags of cement achieved 
significant economy. The placing of successive low lifts in rapid sequence 
also reduces the temperature difference between lifts and largely avoids 
the hazard of progressive cracking. Fly ash will also be used at the 
Little Long and Douglas Point projects. The aggregate for Douglas Point 




LIVE-LINE VIBRATION RECORDER— The Commission has 
developed a prototype recorder for measuring and 
recording vibration of transmission-line conductors while in 
service. The equipment is to undergo further modification. 



82 



Research and Testing Activities 



Nuclear Power Station was found to be potentially reactive with the alkalies in 
cement, and would therefore have required a low-alkali cement. The combination 
of fly ash and normal portland cement will provide a less expensive substitute, 
and will result in less thermal shrinkage of the concrete. 



Soil Mechanics 

Piezometer measurements of pore-water pressures in the reservoir dike at 
Sir Adam Beck-Niagara Pumping-Generating Station indicate that pressures 
under steady water-level conditions are almost exactly those predicted but that 
pressures are considerably higher than expected under draw-down conditions. 
Laboratory studies now being carried out to find a satisfactory explanation for 
this condition should provide information of value for the design of future 
structures. 

The results of triaxial testing of soils as they naturally occur are insufficiently 
consistent to serve as a basis for comparison of shear strengths. In an attempt 
to eliminate the effects of sample variations in testing, a large quantity of clay 

from the Niagara area was dried, 
mixed, and then slurried. Exten- 
sive triaxial tests on this uniform 
material have produced consistent 
results, particularly in regard to 
drained and undrained samples. 
The method developed will be 
adopted for shear testing of soils 
from future projects. 

Thermal Insulation 

With the trend towards in- 
creased use of thermal-electric gen- 
erating facilities, a comprehensive 
program was begun for the evalua- 
tion of insulating materials designed 
for high-temperature applications 
in thermal-electric stations. Equip- 
ment was constructed to measure 
thermal conductivity, hot-surface 
resistance, and the maximum-use 
temperatures of commercial in- 
sulating materials. Manufacturing 
techniques, changes in thermal 
gradients, temperature rise rates, 
and the effects of cycling are 

being studied with a view to eliminating, or at least minimizing, some of the 

defects displayed by the materials. 




MEASURING SHEAR STRENGTHS OF CLAYS — The vane 
apparatus shown is used for laboratory measurement, not 
only in routine testing but also in evaluating, under con- 
trolled conditions, testing techniques which involve the use 
of full-scale field apparatus. 



Elastomers 

Special elastomeric materials are being used for a widening variety of 
applications. As a result, laboratory investigations are being extended for the 



Aids to Operation and Maintenance 



83 



purpose of establishing design and performance standards for the guidance of 
manufacturers. In particular, a low-temperature, vibration-suppressing, organic- 
type rubber is required for use in transmission-line vibration dampers, bundled- 
conductor spacers for extra-high-voltage lines, transformer mounting pads, and 
other applications. A jointing technique was developed for neoprene rubber 
used in the preparation of O-ring gaskets for turbine generators. Specifications 
were raised to take advantage of higher-quality rubbers now available for 
hydraulic gate seals. 

Nuclear Power Station Design 

Investigations have been undertaken and certain recommendations have 
been made with respect to specific problems of design for the Douglas Point 
Nuclear Power Station. A special bituminous coating was recommended for the 
interior of the 400,000-gallon emergency dowse tank, and the use of a resilient 
thiokol filler was recommended for sealing cable ducts entering the reactor area. 
The impermeability to gaseous reactor products of vinyl protective coating for 
walls, and the feasibility of using a spray-applied foamed urethane thermal 
insulation on the exterior of the steel reactor dome were investigated. This 
insulation was evaluated for its durability and its permeability to vapour. 



Aids to Operation and Maintenance 
Synthetic-fibre Ropes 

For certain applications, synthetic-fibre ropes are being used in place of 
manila ropes. Before these new types of rope were adopted for use, comparative 
studies were made of the characteristics and performance of the various types. 
Experience with synthetic- 
fibre ropes has been generally 
favourable and future savings 
through their use may be 
considerable. They have 
proved stronger and more 
durable than manila rope, 
have high resistance to chemi- 
cals and fungi, low moisture 
absorption, and relatively 
high dielectric strength under 
all conditions. Since all cur- 
rently available synthetic- 
fibre ropes are made of 
thermoplastic materials 
having low melting points, 
they are not suitable for 
applications where their 
melting temperatures might 
for any reason be exceeded. 




CLOSED-CIRCUIT TELEVISION CAMERA— A camera, enclosed in 
a metal container 6.5 inches in outside diameter and just visible at 
the left, is used for inspecting locations either dangerous or in- 
accessible to human observers. When it is to be used in murky 
water, the camera is fitted with the removable conical attachment 
shown, which is kept constantly filled with clear running water. 



Closed-circuit Television 

A closed-circuit television camera can now replace the bore-hole and cable- 
duct cameras previously used in viewing hazardous or inaccessible locations. 



84 



Research and Testing Activities 




MEASURING LOAD-CARRYING CAPACITY OF ICE COVER — Using a representative sample core of ice 
obtained by the auger device, left, the small battery-powered meter shown on the right will indicate in tons the 

safe load-carrying capacity of ice cover. 

The camera, fitted with a water-tight case and a clear-water "cone" to facilitate 
observation in murky water, was given a trial use at Lakeview Generating 
Station in an examination of the piling and the lake-bottom, where it proved 
satisfactory for the purpose. The same camera was used to examine the steam 
pipes at Richard L. Hearn Generating Station, and in a much more extensive 
operation for the inspection of nearly 4 miles of 8-inch sewer pipe and some 
6-inch sewer pipe in one of the new municipalities in the St. Lawrence Power 
Project area. 

Wind-speed and Wind-direction Indicator 

Although the spraying by helicopter of rights of way to control woody growth 
is confined for the most part to sparsely settled non-agricultural areas, care must 
be taken to avoid spray drift from the target area. Accurate measurement of 
speed and direction of wind at the height of the flight path is most important. 
A simple indicator was devised using a balloon filled either with hydrogen or 
helium and tethered by a nylon line which, by its relation to established horizon- 
tal and vertical scales, indicates the wind direction and speed. Field trials of 
the instrument indicate that its use will facilitate spraying operations and thereby 
achieve savings. 



Other Investigations 
Electric Water-heating 

Tests and studies were continued with the object of achieving the optimum 
in efficiency, durability, and performance of water-heaters supplied by the 
Commission. Most of the utilities with water-heater rental or sales programs 
specify units approved by the Commission. The one-year survey of the load 
characteristics of heaters equipped with high-wattage upper elements was 



Other Investigations 85 

completed. Preliminary findings were confirmed, that the average demand per 
customer for a large number of these services was considerably less than had 
been supposed. The study contributed to a review of water-heater billing 
demands and of the suitability of high-wattage upper elements for providing 
improved service at little increase in cost to the customers. With a view to 
mitigating the problem of scale deposits on immersion heating elements, field 
tests were made on units equipped with elements of various watts densities, 
watts density being the ratio of power input to surface area of the element. 
Elements with lower watts densities gave the more satisfactory performance 
even in waters where heavy scaling was to be expected. 

Promoting Safe Practices 

On the basis of tests carried out at the Commission's laboratories, instruc- 
tions have been issued on the use of fire-hose streams near live electrical apparatus. 
Lectures and demonstrations have been given to approximately 4,500 persons 
on the feasibility of such operations and the safe operating distances that must 
be observed. Further demonstrations of the same kind are planned. 

In the interests of reducing hazards to men and machines a review was made 
of the operating conditions for the Commission's mobile cranes, which have 
capacities ranging from 5 to 45 tons. In particular, tests devised to indicate the 
distribution of stress in the boom members showed that the stress in one leg of 
the loaded boom of a crane on a 33^-degree slope was 60 per cent greater than if 
the crane were on a level surface. 

A small, portable, battery-powered device was designed and built for 
measuring the load-carrying capacity of an ice sheet. Ice cores required for use 
in the measuring device are obtained by using a core drill designed to be driven 
by an automobile-type starter motor. The motor may be operated from the 
battery of a light vehicle. A meter scale will show quickly and conveniently 
whether a given vehicle may operate safely on the ice cover. 

Protection for Concrete Poles 

Laboratory studies indicate that poles of air-entrained concrete excel those 
of ordinary concrete in their resistance to deterioration from exposure to the 
calcium chloride used in winter for melting snow and ice on roads. It also appears 
that treatment of the pole surfaces with such substances as linseed oil and sili- 
cones provides a means of protecting concrete that has not aged sufficiently to 
offer adequate resistance to the action of chlorides. 



SECTION VI 



STAFF RELATIONS 



THE provision of electric power is basically important in so many ways that 
the general public quite properly expects the maximum guarantee of service 
continuity from those who undertake to supply so indispensable a service. The 
Commission fully appreciates its good fortune in having a staff highly qualified 
in engineering and administrative experience in the performance of this function. 
There is also ample evidence that the loyalty and zeal displayed by the staff in 
the performance of their duty are widely recognized by the customers they serve. 

At the end of 1960 there were 1,618 persons in the Commission's Quarter 
Century Club for employees with long service records, of whom 953 were still 
active members of the staff. Of the active members in this group, all of course 
have served for 25 years or more, and 105 have completed over 40 years of 
service with the Commission. 

86 



Employment Statistics 



87 



Employment Statistics 

The average number of employees declined in 1960 to 15,179, the third 
decline in the past three years. This marks the final stages of a difficult period 
of readjustment following the completion of frequency standardization and of 
certain unusually large construction projects. Over the same three-year period 
more than 1,200 persons, including particularly valuable experienced personnel, 
have been satisfactorily relocated in the organization following completion of 
special tasks to which they had been assigned. Technological improvement 
and the use of automatic equipment, however, have enabled a smaller staff to 
carry the gradually increasing work load. The average staff for the year includes 
12,731 regular and 2,448 temporary employees. The maximum number employed 
during the year occurred in August when there were 16,071 on the staff, including 
the maximum for the year of 3,380 temporary employees engaged for the most 
part in construction. 




LITTLE LONG GENERATING STATION — Members of the supervisory staff and their families are housed in 

these comfortable cottages. A four-room school/ eventually to be expanded to six rooms, provides for the 

grade school education of the children at the project. 



Manpower Planning and Development 

The Commission's staff training programs are being continuously improved 
and expanded. The relatively limited number of trades courses offered ten 
years ago has now been broadened to include training in many trades as well as 
in technical and administrative occupations. For instance, journeymen are 
given theoretical and technical training which they would find difficulty in 
acquiring in their daily work. The training given meter and relay technicians 
will enable them to assist engineers to a greater extent. In the management and 
supervisory courses which were initiated four years ago, the numbers of persons 
participating in 1960 were larger than those in any of the other courses currently 



88 



Staff Relations 




LITTLE LONG GENERATING STATION — A Commission-operated store provides shoppers at this outpost of 
Hydro activity with most of the advantages of the modern urban supermarket. 

being given. In addition, special comprehensive programs have been developed 
to serve specific needs as they arose, for example, in electronic data processing 
and in sales techniques. 

The growing importance of training more senior management personnel was 
critically examined during 1960 and this type of staff development was placed 
upon a more regular basis. Plans were also laid for the evaluation of results 
obtained from the expanded program. 

Industrial Relations 

The Commission renewed agreements with the agencies bargaining on behalf 
of the large majority of the employees — the two principal agencies being the 
Ontario Hydro Employees Union, a local of the National Union of Public Service 
Employees (CLC), and the Allied Construction Council, an association of a 
number of construction craft unions. A settlement with the Employees Union, 
reached only after the commencement of conciliation procedures, was effective 
for one year from April 1, 1960. In addition to wage increases it provided for 
the extension of employee benefits, including a provision for reducing the work 
week for certain weekly-salaried employees in two steps to 35 hours by April 
1961, and an increase in the medical and hospitalization premiums to be assumed 
by the Commission from 70 to 75 per cent of cost. Cost-of-living escalation will 
be eliminated in the future from all contracts of one-year duration. The agree- 
ment reached with the Allied Council was for 18 months commencing July 1, 
1959. 

During the year the employees at the two major thermal-electric stations 
indicated that they no longer wished to be represented by the International 



Accident Prevention 89 

Union of Operating Engineers. An application for certification was made by 
the Canadian Union of Operating Engineers as bargaining agents on their 
behalf. Certification was granted by the Ontario Labour Relations Board on 
December 19, 1960 and negotiations for an agreement with the new Union were 
begun early in 1961. 

The Commission continued an industrial relations service initiated during 
1959 for the purpose of assisting municipal utility management. Several seminars 
were held in association with a committee of the Association of Municipal Elec- 
trical Utilities of Ontario. Further sessions are planned for the guidance of their 
superintendents and foremen in dealing with day-to-day industrial relations 
problems. 

Accident Prevention 

The completion of more than a million man-hours without a lost-time 
injury is a highly commendable achievement. The staffs in three Regions were 
awarded the National Safety Council Award of Merit for achieving this enviable 
record in 1960 — the East Central Region for 1,000,126 man-hours without ex- 
periencing a disabling injury, the Niagara Region for a corresponding 1,463,114 
man-hours, and the Eastern Region for extending their 1959 achievement to 
2,161,669 man-hours. Performance of this quality is a major factor in the 
over-all improvement in the ratios of the number of accidents, and the severity 
of these accidents, to man-hours worked as measured by the American Standards 
Association method. The first, or accident frequency ratio, was reduced by 
15 per cent from 13 per million man-hours in 1959 to 11 per million in 1960. 
The second, or severity ratio, was unchanged from 1959 but was 43 per cent 
lower than the average for the period 1955 to 1959 inclusive. 

The ratio of motor vehicle accidents per 100,000 miles travelled declined 
for the sixth successive year, and at 1.1 marks another very commendable 
achievement. It is 27 per cent below the average for 1955-1959 inclusive. This 
undoubtedly reflects the Commission's insistent emphasis on safe driving prac- 
tices as well as the increased participation by the employees in programs for 
developing safety consciousness. Four employees qualified for participation 
in the Provincial "Roadeo" contest in November 1960. 

Special recognition is given to those employees, who, through the observance 
of good safety practices or the thoughtful application of instruction, have saved 
themselves or others from possible fatal injury. For example, the wearing of 
hard hats is mandatory in certain areas in conformity with sound industrial 
practice. The Commission strongly emphasizes the importance of this instruction 
in commending nine employees who owe their escape from injury to the observ- 
ance of this rule. 

The Canadian Electrical Association Medal Award was given to Mr. J. K. 
Marshall of the Commission's Construction Division and Messrs. F. Ruse, 
E. C. Todd, J. M. Reburn, and D. Eastman of the Lakefront Area staff for 
their part in resuscitating a fellow member of the staff, Mr. Jurij Graf, who had 
suffered severe electric shock. Mr. R. E. Ritchie of the Barrie Rural Operating 
Area was awarded the President's Medal of the National Safety Council for his 
part in resuscitating a man from drowning. 



90 Staff Relations 

Medical Services 

The staff continues to make good use of medical and nursing services pro- 
vided by the Commission, and this may well have been a significant factor in 
maintaining the general health of employees at an above-average level. 

In isolated construction areas where normal facilities for medical service 
are not otherwise available, the Commission establishes its own services for the 
benefit and convenience of the staff. The most recent addition to hospital 
services in the field is the new hospital at Little Long Rapids, which was placed 
in service early in January 1961. 

The Commission, having recently reviewed the operation of the sick leave 
plan, introduced extensive modifications in the plan during 1960 to provide 
improvement in benefits that will apply particularly to employees with records 
of long service. Since health is obviously more likely to decline with advancing 
age, an employee's benefits are no longer limited by the ceiling formerly placed 
on the amount of sick leave that he may accumulate over his years of service. 
For those with 15 years of service, sick leave credits used for an illness will in 
future be re-established on the employee's first policy anniversary following a 
12-month interval and not after a 5-year interval as heretofore. 

First-aid instruction was given in 1960 to approximately 4,100 employees 
throughout the Province. 



APPENDIX I— OPERATIONS 



THE tables in Appendix I are supplementary to the descriptive information 
on the year's operations given in Section I, and to information relating to 
the delivery of power and energy in wholesale quantities given in Section III. 

The table of power resources and requirements gives for each system and in 
total the primary peak requirements for the month of December, and the 
dependable capacity of the Commission's resources at the time these peak 
requirements occurred. A separate table on pages 92 and 93 gives the December 
dependable capacity and maximum output of each Commission-owned station 
and each source of purchased power. The dependable capacity of a station 
is the net output which it can be expected to supply at the time of the system 
primary peak requirements, assuming that all units are available and that the 
supply of water is normal. This capacity may be recalculated from time to 
time in accordance with changing conditions. The capacity of a source of 
purchased power is based on the terms of the purchase contract. 

The Analysis of Energy Sales on pages 96 and 97 shows how the kilowatt- 
hours generated or purchased by the Commission and the associated municipal 
utilities were distributed to the various classes of ultimate customers or to 
interconnected systems. 

Statistics of peak loads and capacities are given, as elsewhere in the Report, 
in kilowatts rather than in horsepower. The kilowatt figures may be converted 
to horsepower by assuming that one horsepower is equivalent to 0.746 kilowatts. 

91 



92 



Appendix I — Operations 
THE COMMISSION'S POWER RESOURCES— 1960 



Southern Ontario System 



River Hydro-electric Generating Stations 

Niagara JSir Adam Beck-Niagara No. 1 . . . 

Sir Adam Beck-Niagara No. 2 . . . 
Pumping-Generating Station. . . 

fOntario Power 

■{■Toronto Power 

Welland Canal DeCew Falls No. 1 

DeCew Falls No. 2 

Muskoka Ragged Rapids 

Big Eddy 

South Muskoka South Falls 

Trethewey Falls 

Hanna Chute 

Beaver Eugenia 

Severn Big Chute 

Saugeen Hanover 

Magnetawan Burks Falls 

Trent Heely Falls 

Ranney Falls 

Meyersburg 

Sidney 

Hagues Reach 

Seymour 

Frankford 

Sills Island 

Otonabee Auburn 

Lakefield 

St. Lawrence Robert H. Saunders-St. Lawrence 
Ottawa Des Joachims 

Otto Holden 

Chenaux 

Chats Falls (Ontario half) 

Madawaska Stewartville 

Barrett Chute 

Calabogie 

Mississippi High Falls 

Galetta 

Rideau Merrickville 

Total hydro-electric 



Location 



Thermal-electric Generating Stations 



Windsor J. Clark Keith (steam) . . . 

Toronto Richard L. Hearn (steam) 

Total thermal-electric 

Total generated — Southern Ontario System. . . 



Sources of Purchased Power 



Detroit Edison Company 

JNiagara Mohawk Power Corporation 

fCanadian Niagara Power Company, Limited. 

Power Authority of the State of New York . . 

Quebec Hydro-Electric Commission 

Gatineau Power Company 

Maclaren-Quebec Power Company 

Ottawa Valley Power Company 

Miscellaneous (relatively small suppliers) .... 

Total purchased — Southern Ontario System 



Dependable 
capacity* 



440,000 

,335,000 

150,000 

135,000 

108,000 

26,000 

130,000 

7,500 

7,100 

4,200 

1,600 

1,200 

5,400 

4.300 

250 

' 11,1 50 

8,350 

5,100 

3,350 

3,250 

2,950 

2,550 

1,550 

1.750 

1,650 

657,000 

372,000 

210,000 

117,000 

82,000 

63,000 

42,000 

4,400 

2,450 

800 

900 



3,948,750 



244,000 
750,000 



994,000 



4,942,750 



15,000 

187,000 

239,000 

93,000 

82,000 



616,000 



Maximum 
output* 



kw 



389,000 

,272,000 

152,000 

138,000 

102,000 

36,000 

134,000 

8.400 

7,950 

4,550 

1,700 

1,400 

5,240 

4,320 

295 

' 12,300 

8,790 

5,700 

3,450 

3,995 

3,160 

2,900 

975 

1,810 

1,590 

752,000 

376,800 

224,400 

117,000 

86,200 

65.500 

42,200 

4,470 

2,800 

335 

278 



187,500 
390,000 



111.000 

210,000 

25,000 

417,000 

248,000 

100,600 

86,200 



Annual energy 
output (net) 



kwh 



2,861,744,800 

8,490.732.300 

119,467,800 

1,062,350,000 

729,747.400 

149,235,100 

822,643,000 

40,304,600 

35,907,565 

26,144,960 

10,658,400 

8,777.900 

25.488,200 

30,241,200 

1,139,520 

198,000 

72,901,740 

54,128,180 

34,769,610 

17,270,400 

19.474,810 

18,034,080 

14,472,000 

5,581,240 

10,241,120 

7,205,080 

6,159,448,000 

2,431,874,500 

1,296,318,600 

747,266,400 

469,660,300 

255,570,300 

225,059,000 

25.882,590 

15,202,560 

3,663.360 

3,568,770 



26.063,437,785 



21,541.200 
143,527.700 



165,068,900 



26,228,506,685 



70,068 

159,591 

109,675 

57,361 

2,696,598 

1,473,915 

632,778 

471,003 

5,319 



,000 

,000 

,000 

,000* 

,000 

,500 

.000 

,700 

,704 



5,676,309,904 



t 25 cycle. 



t 25 and 60 cycle. 



* The power capacity and output referred to in this table are 20-minute peaks for the month of December. Since 
the various maximum outputs do not coincide, their sum is not the peak load of the system. 

'* I? clu ^ es , 49 . 977 . 000 kwh wheeled to Niagara Mohawk Power Corporation for Power Authority of the State of 
New York. 



Capacity and Output of Power Resources 



93 



\ THE COMMISSION'S POWER RESOURCES— 1960 
i 




\ 


Dependable 
capacity* 


Maximum 
output* 


Annual energy 
output (net) 


j 

Northern Ontario Properties 

North eastern Division 

River Hydro-electric Generating Stations 


kw 

232,000 

47,000 

20,000 

10,800 

6.000 

2,700 

8,400 

3,600 

3,000 

2,000 

5,700 

4,100 

2,200 

8.800 

8,200 

1,600 

1,400 

900 


kw 

226,200 

46.000 

20,600 

11,000 

6,000 

2,800 

8.100 

3.970 

3,010 

1,920 

4,200 

4,080 

2,220 

10,120 

8,100 

1,630 

1,430 

890 

450 


kwh 
1.373,388.000 




340,114,560 


Red Rock Falls 


20,496,800 




60,963,444 




44,195.298 




17.879.892 




58.778,000 


Hound Chute 


30,448,400 




11,615,760 




13,505,358 




21,813,360 




29.502,140 


McVittie 


15,816.560 




75,046.240 




51,661,000 




11,052,000 


Elliott Chute 


6,058.133 




5,066,480 




4,354,200 








368,400 

300 

600 

1,000 


467 
654 


2,191,755,625 


Location Diesel-electric Generating Stations 
Kagawong Kagawong (diesel portion) 


560 




1,193,600 




3,223,700 








1,900 




4,417,860 






Total generatec — Northeastern Division 


370,300 

119,200 
76,700 
60,900 
79,300 
65.700 
15,900 
45,500 
25,000 
61,700 
44,000 


120.000 
75,000 
62,000 
79,000 
63.000 
15.000 
48,000 
23,600 
60,000 
46,000 


2,196,173.485 


Northwestern Divi sion 

River Hydro-electric Generating Stations 


667,412.340 




466.507.000 




347,390,200 


English Cai ibou Falls 


462,397,000 




378,133.800 


Ear i'alls 


123,226,800 


Kaministikwia Silver Falls 


136.655,700 




141,049,700 


Winnipeg Whitedo Falls 


311,961,000 


Aguasabon Aguasabo 


253,850,360 


Albany Rat Rapids 


55,800 






Total generated — Northwestern L 'vision 


593,900 
1,200 


16.000 
40,000 

2.650 


3,288,639,700 


Sources of Purchased Power 

NORTHEASTERN DIVISION 

JAbitibi Power & Paper Company, Limited 


9,347,670 


tQuebec Hydro-Electric Commission 


194,654,326 




281,300 


Miscellaneous (relatively small suppliers) 


10,755,650 






Total purchased — Northeastern Division 


1,200 
2,000 


1.828 
77,400 


215,038,946 


NORTHWESTERN DIVISION 

Ontario-Minnesota Pulp & Paper Company 


9,188,758 


Manitoba Hydro- Electric Board 


95,025,450 






Total purchased — Northwestern Division 


2.000 




104,214,208 






Total generated — All systems 


5,906,950 
619,200 




31,713,319,870 
5,995,563,058 


Total purchased — All systems 






Total generated and purchased — All systems 


6,526,150 




37,708,882,928 





«>4 



Appendix I — Operations 







POWER RESOURCES 




December dependable 




Commission stations 




Hydro-electric 


Thermal -electrict 


Total 


Southern Ontario System 1960 

1959 
Northern Ontario Properties 

Northeastern Division 1960 

1959 

Total 1960 

1959 
Net increase or decrease 


kw 
3,948,750 
3,979,700 

368,400 

342.400 

4,317,150 

4.322,100 

30,950 

26,000 

4,950 

593.900 
593,900 



4,911,050 
4,916,000 


kw 
994,000 
616,000 

1,900 

1,800 

995.900 

617,800 

378,000 

100 

378,100 






995,900 
617,800 


kw 

4,942,750 
4,595.700 

370.300 

344,200 

5.313.050 

4,939,900 

347,050 




26,100 


Total 


373,150 


Northern Ontario Properties 

Northwestern Division 1960 

1959 
Net increase or decrease 


593.900 
593.900 




Total— All systems 1960 

1959 


5,906,950 
5,533,800 



* The capacities shown are those available for a 20-minute period at the times of system primary peak demand in each 
of the three operating systems in December, the capacity of sources of purchased power being based on the terms of 
the purchase contract. Requirements shown are the December coincident peaks for each system and their arith- 
metic sum. 



ANNUAL ENERGY 



Energy Made Available by the Commission 





1959 


1960 


Increase 

or 
decrease 


Southern Ontario System 
Generated (net) 


kwh 

24,206,123,608 
336,678,700 


kwh 

26,063,437,785 
165,068,900 


per cent 

7.7 


thermal-electric 


51.0 


Total generated 


24,542,802,308 
5,550,093,709 
1,518,561,000 

25,226,264,417 
3,348,070,600 


26,228,506,685 
5,676,309,904 
1,357,163,000 

26,321,728,089 
4,225,925,500 


6.9 
2.3 


Transferred* in or out (net) . 


10.6 
4 3 




26 2 






Total 


28,574,335,017 28,574,335,017 

1,911,774,236 
3,859,560 


30,547,653,589 30,547,653,589 

2,191,755,625 
4,417,860 


6.9 


Northern Ontario Properties 
northeastern division 
Generated (net) 

hydro-electric 


14 6 




14 5 






Total generated 


1,915,633,796 

181,125,014 

1,518,561,000 

3,559,611,260 
55,708,550 


2,196,173,485 

215,038,946 

1,357,163,000 

3,636,699,913 
131,675,518 


14.6 

18 7 


Transferred* in or out (net) . 
Primary 


10.6 


Secondary 


136.4 




Total ' 

NORTHWESTERN DIVISION 

Generated (net) 

hydro-electric 


3,615,319,810 3,615,319,810 

3,141,952,852 

133,806,605 

2,760,792,799 
514,966,658 


3,768,375,431 3,768,375,431 

3,288,639,700 

104,214,208 

2,759,000,194 
633,853,714 


4.2 

4.7 

22.1 

0.1 
23.1 


Purchased 


Primary 






Total 

All Systems 

Generated (net) 

hydro-electric 


3,275,759,457 3,275,759,457 

29,259,850,696 
340,538,260 


3,392,853,908 3,392,853,908 

31.543.833,110 
169,486,760 


3.6 

7.8 
50.2 


thermal- and diesel-electric 


Total generated 

Purchased 


29,600,388,956 
5,865,025,328 

31,546,668,476 
3,918,745,808 


31,713,319,870 
5,995,563,058 

32,717,428,196 
4,991,454,732 


7.1 
2.2 

3.7 
27.4 


Primary 






Total 


35,465,414,284 35,465,414,284 


37,708,882,928 37,708,882,928 


6.3 



* Net interchange between Southern Ontario System and Northeastern Division of the Northern Ontario Properties 



Resources and Loads 



95 



AND REQUIREMENTS 



capacity* 


Primary power 
requirements* 


Reserve 




Sources of 

purchased 

power 


Total 
dependable 
capacity* 


Ratio of 

reserve to 

requirements 


kw 

616,000 
618,000 

1,200 

1,200 

617,200 

619,200 

2,000 



2,000 

2.000 
1,700 

300 

619,200 
620,900 


kw 
5.558,750 
5.213,700 

371.500 

345,400 

5,930,250 

5,559,100 

345,050 

26,100 

371,150 

595.900 
595,600 

300 

6,526,150 
6,154,700 


kw 
4,772,583 
4,578,541 

551,661 

550,067 

5.324,244 

5,128,608 

194,042 

1,594 

195,636 

421.438 
427,866 

6,428 

5,745,682 
5,556,474 


kw 

606,006 
430,492 

174,462 
167,734 

** 
** 


per cent 

11.4 
8.4 

41.4 
39.2 

** 
** 



** There is no interconnection between the Northwestern Division and the other operating systems of the Commission. 
t Includes diesel-electric. 



ACCOUNT 



Energy Disposed of by the 


Commission in Wholesale Quantities 




1959 


1960 


Increase 

or 
decrease 


Southern Ontario System 


kwh 

15,980,829,118 

4,616,784 

411,698,482 

2,310,451,148 

4,118,441,003 


kwh 

16,828,812,615 

4,972,000 

421,380,355 

2.508,393,230 

4,218.341.434 


per cent 
5.3 




7.7 


— Interconnected systems, for resale. . . . 


2.4 
8.6 


— Direct industrial customers 


2.4 




22,826,036,535 

3,183.489,320 

4,942,800 


23.981,899,634 
4,005.775.000 


5.1 


Secondary — Interconnected systems, for resale. . . 


25.8 










3.188.432,120 


4,005,775,000 


25.6 








26,014,468,655 
2,559,866,362 


27,987,674,634 
2,559,978,955 


7 6 


Losses and unaccounted for 




Total 


28,574,335,017 

301,070,237 

172,927,485 

15,485,020 

272,253,723 

2,414,865,353 


30,547,653.589 

377.674,126 

182,088,374 

17,706,000 

261,457,029 

2,424,728,620 


6.9 


Northern Ontario Properties 
northeastern division 


25.4 




5 3 


— Interconnected systems, for resale. . . . 


14.3 
4.0 


— Direct industrial customers 


0.4 




3,176,601,818 

36,337 

55,051,200 


3.263,654,149 


2 7 






— Direct industrial customers 


129,101,838 


134.5 


Total secondary 


55,087,537 


129,101,838 


134.4 




3,231,689,355 
383,630,455 


3,392,755,987 
375,619,444 


5.0 




2 1 






Total 


3,615,319,810 

473,203,775 
18,082,895 


3,768,375,431 

495.306,036 
18,686,852 


4 2 


northwestern division 

Primary — Municipal electrical utilities 


4.7 
3 3 








72,200,621 
2,016,322,235 


80.860,767 
1,999,633.946 


12 


— Direct industrial customers 


0.8 


Total primary 

Secondary — Interconnected systems, for resale. . . 
— Direct industrial customers 


2,579,809,526 
189,147,313 
290,671,340 


2.594,487,601 
261,272,937 
318,655,629 


0.6 

38.1 

9.6 


Total secondary 


479,818,653 


579,928,566 


20.9 




3,059,628,179 
216,131.278 


3,174.416,167 
218,437,741 


3 8 




1 i 






Total 

All Systems 

Primary 


3,275,759,457 

28,582,447,879 
3,723,338,310 
3,159,628,095 


3,392,853,908 

29,840,041,384 
4,714,805,404 
3,154,036,140 


3.6 

4 4 




26 6 


Losses and unaccounted for 


0.2 


Total 


35,465,414,284 


37,708,882,928 


6.3 



96 



Appendix I — Operations 



ANALYSIS OF 
by the Commission and Associated 





Sales by 

utilities 

listed in 

Statement A 


Sales by The 




Through 

local 
systems 


Classes of ultimate customers served: 


kwh 
6,823,369,181 


kwh 
121,289,909 




















6,823,369,181 
2,870,753,176 
7,310,504,032 


121,289,909 




50,917,141 




16,178,993 














253,663,067 


2,732,885 






Total sales to ultimate customers served 


17,258,289,456 


191,118,928 


Delivered to interconnected systems for resale: 
















Total sales to ultimate customers and for resale 


17,258,289,456 

850,234,801 
210,053,034 

196,678,446 


191,118,928 


Adjustments: 








Purchased by utilities listed in Statement A from sources 
other than the Commission 








Commission sales, wholesale and retail 


17,701,792,777 


191,118,928 




14,628,298 


♦Disposed of by the Commission in wholesale quantities 


17,701,792,777 


205,747,226 



This line gives the sums of the corresponding items shown on the preceding page for each of the three operating 
systems. The total of 34,554,846,788 kilowatt-hours plus transmission losses and unaccounted for amounting to 
3.154,036,140 kilowatt-hours equals the 37,708,882,928 kilowatt-hours shown as generated and purchased. 



Analysis of Energy Sales 



97 



ENERGY SALES 

Municipal Electrical Utilities during 1960 



Hydro- Electric Power Commission of Ontario 




In rural areas 


To direct 
industrial 
customers 


To interconnected 
systems for resale 


Total 


kwh 


kwh 


kwh 


kwh 
6,944,659,090 


1 070 637 716 






1,070,637,716 


67,785,615 






67,785,615 








1,138 423 331 






8,083,082,421 


301 874 591 






3,223,544,908 


325,416 458 


8,642,704,000 
447,757,467 




16,294,803,483 






447,757,467 


850,192,892 




850,192,892 


11,834,385 






268,230,337 










2,627.741,657 


9,090,461,467 




29,167,611,508 




439,086,355 
4,267,047,937 


439,086,355 






4,267,047,937 








2,627,741,657 


9,090,461,467 


4,706,134,292 


33,873,745,800 
850,234,801 








2 J 0,0 5 3, 034 








196,678,446 










2,627,741,657 
222,969,369 


9,090,461,467 


4,706,134,292 


34,317,249,121 
237,597,667 


2,850,711,026 


9,090,461,467 


4,706,134,292 


34,554,846,788 



APPENDIX II -FINANCIAL 

Table of Financial Statements 

Balance Sheets Page 

Southern Ontario System 28 

Northern Ontario Properties 30 

Statements of Operations 

Southern Ontario System 32 

Northern Ontario Properties 33 

Statement of Funded Debt 34 

Statement of Advances from the Province of Ontario 36 

Southern Ontario System 

Fixed Assets 100 

Accumulated Depreciation 104 

Frequency Standardization 105 

Exchange Discount (Net) on Funded Debt 105 

Reserves 

Stabilization of Rates and Contingencies 106 

Sinking Fund 107 

Allocation of the Cost of Primary Power 108 

Sinking Fund Equity 128 

Northern Ontario Properties 

Fixed Assets 136 

Accumulated Depreciation 140 

Frequency Standardization 140 

Exchange Discount (Net) on Funded Debt 140 

Reserves 

Stabilization of Rates and Contingencies. 141 

Sinking Fund 141 

Allocation of the Cost of Primary Power 142 

Sinking Fund Equity 146 

99 



100 



Appendix II — Financial 

SOUTHERN ONTARIO 

FIXED 

Statement Showing Changes during 





In 




Balance 

January 1, 

1960 


Changes 


Property 


Placed 

in 
service 


Equipment 
relocated 

and 
reclassified 


Power System 

Hydro-electric Generating Stations 
Niagara River 

Sir Adam Beck-Niagara No. 1 

Sir Adam Beck-Niagara No. 2 

Ontario Power 


$ 

83,896,214 

311,084,663 

21,975,068 

11,546,880 

27,425,890 

281,159,873 

73,249,077 

58,004,954 

29,351,613 

9,302,914 

5,052,955 

12,450,473 

4,885,015 

20,450,542 


$ 

1,677,499 

99,353 

9,699 

1,262 

16,129 

10,488,255 

7,290 

165,383 

9,251 

16,987 


1,578,696 
122,526 


Toronto Power 


2,400 


Welland Canal 

DeCew Falls 


3,794 


St. Lawrence River 

St. Lawrence Power Project 

Ottawa River 

Des Joachims 


393,255 


Otto Holden 


4,381 


Chenaux 


6,424 


Chats Falls 

Ogoki Diversion 


598,644 


Madawaska River 

Stewartville 


1,007 

27 

42,702 




Barrett Chute. . . . 




Other properties 


10,954 








949,836,131 


12,532,776 


694,932 


Thermal-electric Generating 
Stations 
J. Clark Keith 


46,440,949 
47,974,863 


8,795 
50,864,193 




Richard L. Hearn 


1 1 ,900 


Lakeview 




Douglas Point (Nuclear) 
— Ontario Hydro contribution . . 








Other properties 


488,418 


149,631 


11,900 








94,904,230 


51,022,619 








Total generating stations 


1,044,740,361 


63,555,395 


694,932 


Transformer Stations 

230-kv 


94,614,112 

102,517,231 

7,470,865 

24,708,166 


3,700,631 
8,397,829 
1,016,912 
2,995,667 


1,297,229 


Other — Niagara Division 


451,539 


— Georgian Bay Division 

— Eastern Ontario Division 


194,672 
149,675 


Total transformer stations 


229,310,374 


16,111,039 


800,693 


Transmission Lines 

230-kv 


100,812,857 

64,758,195 

8,446,720 

24,913,634 


1,544,398 

3,479,855 

584,151 

840,385 


1,262,943 


Other — Niagara Division 


614,142 


— Georgian Bay Division 

— Eastern Ontario Division 


35,879 
264,408 


Total transmission lines 


198,931,406 


6,448,789 


348,514 







Southern Ontario System — Fixed Assets 
SYSTEM 
ASSETS 
Year 1960 and Balances at December 31, 1960 



101 



service 


Under 

construction 

December 31, 

1960 


Total 

fixed assets 

December 31, 

1960 




during year 


Balance 

December 31, 

1960 




Sales 

and 

retirements 


Expenditures 

during 

1960 


58,652 

24,023 

18,250 

2,717 


87,093,757 

311,282,519 

21,966,517 

11,547,825 

27,447,202 

291,254,873 

73,255,397 

58,171,384 

29,353,440 

8,563,817 

5,052,955 

12,449,466 

4,883,692 

20,466,951 


$ 

168,955 

448,889 

9,560 


$ 

87,262,712 

311,731,408 

21,976,077 

11,547,825 

27,451,845 

291,396,751 

73,302,947 

58,187,219 

29,356,833 

8,597,332 

5,052,955 

12,449,466 

4,886,029 

20,635,028 


$ 

1,045,558 

431,563 

9,699 

1 262 


8,977 


4,643 

141,878 

47,550 

15,835 

3,393 

33,515 


16,661 
7,313,212 


970 

3,334 

1,000 

157,440 


37,780 
3,961 
6,865 

28,971 






1 007 


1,296 


2,337 
168,077 




15,339 


93,356 


274,044 


962,789,795 


1,044,632 


963,834,427 


8,987,881 




46,449,744 
98,850,956 


3,135 
41,113,364 
42,858,354 

637,161 
340,582 


46,452,879 
139,964,320 

42,858,354 

637,161 
965,729 


5,848 




17,713,308 




24,353,250 






637,161 


1,002 


625,147 


208,381 


1,002 


145,925,847 


84,952,596 


230,878,443 


42,501,186 


275,046 


1,108,715,642 


85,997,228 


1,194,712,870 


51,489,067 


6,480,815 

3,774,063 

336,072 

588,582 


90,536,699 

107,592,536 

8,346,377 

26,965,576 


2,032,649 

2,581,323 

43,442 

248,113 


92,569,348 

110,173,859 

8,389,819 

27,213,689 


3,478,418 

8,242,336 

873,410 

2,396,970 


11,179,532 


233,441,188 


4,905,527 


238,346,715 


14,991,134 


134,283 
695,500 
131,832 
108,703 


103,485,915 

66,928,408 

8,863,160 

25,380,908 


6,418,190 

2,793,989 

147,314 

800,712 


109,904,105 

69,722,397 

9,010,474 

26,181,620 


5,285,980 

4,215,996 

419,248 

735,689 


1,070,318 


204,658,391 


10,160,205 


214,818,596 


10,656,913 



102 



Appendix II — Financial 



SOUTHERN ONTARIO 

FIXED 

Statement Showing Changes during 





In 




Balance 

January 1, 

1960 


Changes 


Property 


Placed 

in 
service 


Equipment 
relocated 

and 
reclassified 


Power System — (continued) 

Local Systems 

Georgian Bay Division 


$ 
425,811 


$ 
10,905 


$ 
2,457 


Communications 


11,530,608 


280,529 


310,031 






Total power system 


1,484,938,560 


86,406,657 


69,735 






Administrative and Service 
Buildings and Equipment 

Buildings 


22,857,189 
7,209,069 


645,726 
519,174 


75,526 


Office and Service Equipment 






Total administrative and service 
buildings and equipment 


30,066,258 


1,164,900 


75,526 


Rural Power District 


213,214,771 


15,044,575 


5,791 






Total Fixed Assets 


1,728,219,589 


102,616,132 









Changes in Assets under Construction during 1960 

Under construction at January 1, 1960 % 112,306,246 

Expenditures during 1960 94,534,086 



Less — Placed in service during 1960 



206,840,332 
102,616.132 



Under construction at December 31, 1960 $ 104,224,200 



Southern Ontario System — Fixed Assets 



103 



SYSTEM 

ASSETS 

Year 1960 and Balances at December 31, 1960 



service 


Under 

construction 

December 31, 

1960 


Total 

fixed assets 

December 31, 

1960 




during year 


Balance 

December 31, 

1960 




Sales 

and 

retirements 


Expenditures 

during 

1960 


$ 
4,979 


$ 
429,280 


418 


429,698 


$ 
9,224 


348,868 


11,152,238 


326,113 


11,478,351 


398,256 


12,878,743 


1,558,396,739 


101,389,491 


1,659,786,230 


77,544,594 


52,467 
252,235 


23,525,974 
7,476,008 


1,188,387 


24,714,361 
7,476,008 


1,372,752 
519,174 








304,702 


31,001,982 


1,188,387 


32,190,369 


1,891,926 


3,493,636 


224,759,919 


1,646,322 


226,406,241 


15,097,566 


16,677,081 


1,814,158,640 


104,224,200 


1,918,382,840 


94,534,086 



Summary of Sales and Retirements during 1960 

Charged to operations $ 45,457 

Charged to reserve for stabilization of rates and contingencies 

— Leaside Transformer Station $ 850,922 

—Miscellaneous 55,097 

906,019 

Charged to construction in progress 1,347,204 

Charged to accumulated depreciation 12,317,377 

Proceeds from sales 2,061,024 

$ 16,677,081 



104 



Appendix II — Financial 



SOUTHERN ONTARIO 



ACCUMULATED DEPRECIATION 
December 31, 1960 





Power 

System 


Rural Power 
District 


Administrative 

and service 

buildings and 

equipment 


Total 


Balances at January 1, 1960 . 
Add: 

Interest at 3% per annum 
on accumulated deprecia- 
tion on plant not fully 

depreciated 

Provision in the year 


$ 
163,754,000 

3,992,216 

13,074,301 
10,188 

28,161 

73,782 


$ 
46,083,895 

1,387,279 
6,213,824 


$ 
6,904,364 

69,176 


$ 
216,742,259 

5,448,671 
19,288,125 




876,667 
16,212 


886,855 


Adjustments re transfer of 
equipment 


11,949 
1,738 




75,520 








180,876,326 


53,698,685 


7,866,419 


242,441,430 


Deduct: 

Cost of fixed assets retired 
less proceeds from sales 
(Note) 


9,348,113 
292,005 


2,773,788 
44,315 


195,476 
2,284 


12,317,377 


Excess or deficiency of re- 
moval costs over salvage 
recoveries on assets retired 


249,974 




9,640,118 


2,729,473 


197,760 


12,567,351 


Balances at December 31, 1960 


171,236,208 


50,969,212 


7,668,659 


229,874,079 



Note: Accumulated depreciation for the Power System includes a special allowance for estimated capital losses on 
25-cycle equipment to be retired as a result of frequency standardization. A summary of the charges against 
this special allowance in 1960 is noted below: 

Balance at January 1, 1960 $ 8,000,000 

Deduct charges in 1960: 

Losses incurred on the retirement of 25-cycle equipment 
(included above in "Cost of fixed assets retired less pro- 
ceeds from sales") $ 1,910,558 

Other expenditures and removal costs 90,727 

2,001,285 

• 
Balance at December 31. I960 $ 5,998,715 



Southern Ontario System — Frequency Standardization 105 

SYSTEM 

FREQUENCY STANDARDIZATION ACCOUNT 
December 31, 1960 

Balance at debit at January 1 , 1960 $199,353,727 

Less portion of cost charged to cost of power for the year 10,805,643 

Balance at debit at December 31, 1960 $188,548,084 



EXCHANGE DISCOUNT (NET) ON FUNDED DEBT 
December 31, 1960 





Discount 


Premium 


Net discount 


Exchange discount and premium on funded 
debt issued in United States funds: 

Balances at January 1, 1960 

Less discount and premium at time of issue 
on bonds redeemed during 1960 


$ 

5,496,338 
91,769 


$ 

4,746,301 
11,735 


$ 

750,037 
80,034 






Balances at December 31, 1960 


5,404,569 


4,734,566 


670,003 



106 



Appendix II — Financial 



SOUTHERN ONTARIO 

STATEMENTS OF RESERVES, 

Stabilization of Rates 





Power 
System 


Rural Power 
District 




$ 
114,062,085 

4,678,759 
4,054,410 


$ 
2,709,752 

100,929 


Add: 

Interest for year on reserve balances 


Excess of revenue over costs of supplying power to Rural 
Power District customers 


944,626 


Profit on redemption of funded debt and sale of invest- 
ments, net 


648,127 








123,443,381 


3,755,307 


Deduct: 

Expenditures during year 






Withdrawal in the year applied in reduction of cost of 
power 






Cost of repairs to facilities damaged by ice storm 

Loss on equipment retired prematurely to permit an 
increase in the capacity of Leaside Transformer 
Station 


269,420 

850,922 
115,900 


1,244,099 


Miscellaneous charges 










1,236,242 


1,244,099 


Balances at December 31, 1960 


122,207,139 


2,511,208 







Southern Ontario System — Statements of Reserves 
SYSTEM 
DECEMBER 31, 1960 
and Contingencies 



107 





Portion of reserve earmarked for g 


pecial purposes 




Sub-total 


Maximum 
power cost 


Municipal direct 
customers 


Nuclear 
research 


Total 


116,771,837 


$ 
461,032 

18,441 


$ 


$ 
3,295,948 

111,083 
407,520 


$ 
120,528,817 


4,779,688 




4,909,212 


4,054,410 


394,519 


4,856,449 


944,626 




944,626 


648,127 








648,127 












127,198,688 


479,473 


394,519 


3,814,551 


131,887,231 








2,040,646 


2,040,646 




18,441 


18,441 


1,513,519 






1,513,519 


850,922 








850,922 


115,900 








115,900 












2,480,341 


18,441 




2,040,646 


4,539,428 








124,718,347 


461,032 


394,519 


1,773,905 


127,347,803 



Sinking Fund 





Power System 

and Rural 
Power District 


Administrative 

and service 

buildings and 

equipment 


Total 


Balances at January 1, 1960 

Add: 

Interest at 4% per annum on reserve balances 
Provision in the year — direct 


$ 
279,872,268 

11,194,891 

17,548,125 

4,862 


$ 
3,610,148 

144,406 


$ 
283,482,416 

11,339,297 

17,548,125 


— indirect 


243,209 


248,071 




308,620,146 


3,997,763 


312,617,909 


Deduct credits resulting from matured sinking 
funds (see note): 
Interest 


665,902 
175,299 


41,435 
10,907 


707,337 


Principal 


186,206 




841,201 


52,342 


893,543 


Balances at December 31, 1960 


307,778,945 


3,945,421 


311,724,366 



Note: The matured sinking funds at January 1, 1960 amounted to $17,683,445. 



108 



Appendix II — Financial 



SOUTHERN ONTARIO 

STATEMENT OF THE ALLOCATION 

for the Year 





Power and energy 

supplied during year 

(principal bases 

of cost allocation) 


Cost of 


Municipality 


Average of 

monthly 
peak loads 


Energy 


Power 

purchased, 

operating 

costs, and 

fixed 

charges 

(Note 2) 


Frequency 
standardi- 
zation 

(Note 3) 


Provision 

for 

stabilization 

of rates and 

contingencies 

(Note 4) 




kw 

3,598.1 

301.8 

5,351.2 

1,773.4 

402.9 
1.720.6 
1,357.4 

228.5 

3,031.6 

2,027.4 

87.7 

309.3 

3.964.1 
695.2 
381.0 

4,506.0 

147.5 

3,716.0 

629.5 

819.1 

1,176.9 

15,852.3 

332.9 

286.9 

2,182.8 

1.328.4 

1,079.5 

424.3 

607.5 

20.652.0 

1.298.7 

390.0 

585.3 

674.3 

1.004.5 

335.7 


megawatt- 
hours 
17.448.8 
1.241.6 
28,048.4 
8,328.9 

1.754.7 

9.854.9 

6.429.7 

913.2 

17.089.5 

9.827.8 

378.4 

1.318.4 

18,998.7 
3,007.3 
1,868.4 

24,541.5 

596.0 

19,147.2 
2,701.2 
3,005.5 

5,297.6 

88,072.8 

1,564.6 

1,419.2 

14,133.4 
6.719.1 
5,302.1 
1.956.0 

2.934.2 

113.562.8 

6.342.9 

1.622.4 

2,785.2 
3,240.0 
5,007.9 
1.530.4 


$ 
136,812 

11,962 
187,649 

70,987 

14,800 

73,744 

50,564 

9,138 

117,758 
72,598 
3.423 
12.240 

147.243 
27.685 
14.799 

164.021 

5,450 

131,346 

24,919 

27,990 

46,850 

546,443 

13.735 

11,543 

82,618 
48,940 
44,108 
18,895 

24,504 

699.905 

50,151 

14,119 

23,632 
26,981 
40.174 

13,577 


$ 
17,990 
1.509 


3,598 




302 




5,351 






1,773 


Alfred 




403 






1,721 






1,357 




1.143 

15.158 
10,137 


228 




3,032 




2,027 


Apple Hill. . . 


88 


Arkona 


1.546 


309 


Arnprior 


3,964 


Arthur 




695 


Athens 




381 


Aurora 


22,530 


4,506 


Avonmore 


148 


Aylmer 


18.580 
3,148 
4.095 


3,716 


Ayr 


630 


Baden 


819 


Bancroft 


1,177 


Barrie 




15,852 


Barry's Bay 




333 


Bath 




287 




10,914 
6.642 


2,183 




1,328 


Beaverton 


1,080 






424 


Belle River 


3,038 


607 


Belleville 


20,652 




6,493 


1,299 




390 


Blyth 


2,927 


585 




674 


Bolton 


5,022 
1,679 


1,005 


Bothwell 


336 







Southern Ontario System — Cost of Primary Power 



109 



SYSTEM 



OF THE COST OF PRIMARY POWER 
Ended December 31, 1960 



primary power 


Amounts 

billed 

for primary 

power 

(municipalities 

at interim 

rates) 


Balance 
credited 

or 
charged 


Annual rates on 
a kilowatt basis 


Provision 

for 

nuclear 

research 

(Note 5) 


Credit 
resulting 

from 

matured 

sinking fund 

(Note 1) 


Total cost 

of 

primary power 


Interim 


Actual 


$ 

327 

25 

505 


$ 
1,357 
220 


$ 
157,370 

13,578 
193,505 

72,919 

15,238 
75,441 
52,044 
10,528 

134,725 

84,946 

3,518 

14,121 

151,566 
28,441 
15,215 

191,490 

5,610 

153,709 

27,993 

31,571 

48.131 

556,637 

14,098 

11,856 

94,102 
57.033 
41,521 
19,228 

28,204 

722,551 

57,839 

14,542 

27,197 
27,716 
46.106 
15,401 


$ 
158,459.36 

14,005.44 
193,981.00 

72.886.06 

15.612.07 
78.288.83 
50,900.94 
10.668.62 

139,455.14 

86,973.33 

3,446.94 

14,615.22 

149.841.11 
29,544.58 
15.050.47 

198,713.88 

5.456.27 

159,786.57 

28,263.42 

32,681.11 

50.019.68 

570.682.80 

15,147.71 

11.333.55 

98,009.60 
60,109.73 
44,257.44 
19,601.91 

28,429.05 

722,819.43 

58.962.11 

14.546.38 

27,655.05 
27,038.45 
47,011.38 
16.114.00 


$ 

1,089.36 

427.44 

476.00 

32.94 

374.07 
2,847.83 
1,143.06 

140.62 

4,730.14 

2,027.33 

71.06 

494.22 

1,724.89 

1,103.58 

164.53 

7,223.88 

153.73 
6,077.57 

270.42 
1,110,11 

1,888.68 

14,045.80 

1,049.71 

522.45 

3,907.60 

3,076.73 

2,736.44 

373.91 

225.05 

268.43 

1,123.11 

4.38 

458.05 
677.55 
905.38 
713.00 


$ 
44.04 
46.40 
36.25 
41.10 

38.75 
45.50 
37.50 
46.70 

46.00 
42.90 
39.30 
47.25 

37.80 
42.50 
39.50 
44.10 

37.00 
43.00 
44.90 
39.90 

42.50 
36.00 
45.50 
39.50 

44.90 
45.25 
41.00 
46.20 

46.80 
35.00 
45.40 
37.30 

47.25 
40.10 
46.80 
48.00 


$ 
43.74 
44.99 
36.16 


159 




41.12 


35 




37.82 


170 
123 


194 


43.85 
38.34 


19 




46.07 


296 
184 


1,519 


44.44 
41.90 


7 




40.11 


26 




45.65 


359 




38.23 


61 




40.91 


35 




39.93 


433 




42.50 


12 




38.03 


348 
54 
66 

104 


281 

758 

1,399 


41.36 
44.47 
38.54 

40.90 


1,539 
30 


7,197 


35.11 
42.35 


26 




41.32 


229 
123 


1,842 


43.11 
42.93 


99 
38 

55 


3,766 
129 


38.46 
45.32 

46.43 


1,994 




34.99 


119 
33 


223 


44.54 
37.29 


53 




46.47 


61 




41.10 


93 
30 


188 
221 


45.90 
45.88 



110 



Appendix II — Financial 



SOUTHERN ONTARIO 

STATEMENT OF THE ALLOCATION 

for the Year 



Municipality 



Power and energy 

supplied during year 

(principal bases 

of cost allocation) 



Average of 

monthly 
peak loads 



Energy 



Cost of 



Power 

purchased, 

operating 

costs, and 

fixed 

charges 

(Note 2) 



Frequency 
standardi- 
zation 

(Note 3) 



Provision 

for 

stabilization 

of rates and 

contingencies 

(Note 4) 



Bowmanville . . 
Bracebridge . . . 

Bradford 

Braeside 

Brampton 

Brantford 

Brantford Twp 
Brechin 

Bridgeport. . . . 

Brigden 

Brighton 

Brockville 

Brussels 

Burford 

Burgessville. . . 
Burk's Falls . . . 

Burlington. . . . 

Caledonia 

Campbellford. 
Campbellville. 

Cannington. . . 

Cardinal 

Carleton Place 
Casselman. . . . 

Cayuga 

Chalk River . 

Chatham 

Chatsworth . . . 

Chesley 

Chesterville. . . 
Chippawa. . . . 
Clifford 

Clinton 

Cobden 

Cobourg 

Col borne 



kw 

5,704.6 

33.2 

1,591.2 

1,585.6 

10,499.3 

42,368.3 

5,000.8 

125.6 

778.5 

225.1 

1,286.9 

14.848.7 

598.0 
734.9 
194.0 
521.9 

27,352.2 
913.6 
924.0 
146.1 

589.7 

833.3 

2,857.2 

628.7 

388.1 

414.0 

19,141.8 

243.6 

1,119.4 

1,311.4 

1,116.6 

333.7 

2,078.0 
568.8 

8,795.0 
790.9 



megawatt- 
hours 
28,235.9 

8,503.2 
5,847.4 

53,514.9 

217,641.3 

25,503.3 

568.4 

3,496.4 

945.2 

7,031.7 

74,792.7 

2,632.0 
3,223.8 

648.8 
2,515.2 

144,347.9 
4,689.6 
1,324.5 

658.8 

2,804.8 

4,325.7 

15,373.8 

2,617.6 

1,812.4 

2,228.4 

94,216.4 

1,102.0 

4,679.2 
6,003.5 
5,902.0 
1,685.6 

10,176.4 
2,570.4 

44,607.5 
4,117.4 



$ 

197,847 

2,224 

63,040 

50,575 

352,516 

1,398,220 

179,523 

5,160 

27,999 

8,956 

48,674 

485,198 

23,747 

26,678 

6,799 

21,238 

971,998 

33,905 

24,291 

5,612 

25,026 

32,814 

117,260 

24,659 

15,314 

15,524 

623,059 

10,315 

42,750 
51,739 
42,344 
13,664 

76,254 

19,797 

298,272 

33,728 



52,496 

211,842 

25,004 



3,892 
1,126 



2,990 

3,674 

970 



136,761 
4,568 



731 



1,940 
95,709 



5,583 
1,669 



10,390 



5,705 

33 

1,591 

1,586 

10.499 

42,368 

5,001 

126 

779 

225 

1.287 

14,849 

598 
735 
194 
522 

27,352 
914 
924 
146 

590 

833 

2,857 

629 

388 

414 

19,142 

244 

1,119 

1,311 

1,116 

334 

2.078 
569 

8.795 
791 



Southern Ontario System — Cost of Primary Power 



111 



SYSTEM 

OF THE COST OF PRIMARY POWER 
Ended December 31, 1960 



primary power 



Provision 

for 
nuclear 
research 

(Note 5) 



Credit 
resulting 

from 

matured 

sinking fund 

(Note 1) 



Total cost 

of 

primary power 



Amounts 

billed 

for primary 

power 

(municipalities 

at interim 

rates) 



Balance 
credited 

or 
charged 



Annual rates on 
a kilowatt basis 



Interim 



Actual 



524 

2 

151 

129 

978 

3.961 

466 

11 

69 

19 

124 

1.376 

52 
63 
16 

47 

2.590 
86 
57 
13 

53 

79 

273 

53 

34 

40 

1.755 

21 

96 
116 
106 

31 

190 
50 

817 
74 



4,754 
17,227 



1,769 



148 
3,322 



420 

5 
3,187 



3,467 



3,585 

77 



2,369 



% 

204,076 

2,259 

64.722 

52.290 

411.735 

1.639.164 

209,994 

3,528 

32.739 

10,178 

50,085 

498,101 

27,387 

31,084 

7,938 

21,807 

1,138,701 

39,053 

25.272 

6.497 

22.482 

33.726 

120,390 

25.341 

17.676 

15.978 

736,198 

10.580 

43.965 
49.581 
49,072 
15,698 

86.543 

20.416 

307.884 

34,593 



$ 

202,511.52 

1,095.05 

65,876.40 

53,512.60 

410,521.66 

1,669,310.71 

217,034.37 

3,892.33 

33,630.12 

10,378.65 

49.546.29 

503,369.84 

28.255.91 

31,675.99 

8.167.75 

24,214.25 

1,155,630.82 

39,467.88 

33,263.10 

6,646.79 

24.356.34 
34.581.97 
118,859.86 
26,090.36 

17,929.46 

16,561.02 

748.443.73 

10.718.77 

44,774.67 
50,487.63 
49,351.51 
15,750.26 

89,560.37 

20.247.81 

325.414.39 

33.691.64 



$ 
1,564.48 
1,163.95 
1,154,40 
1,222,60 

1,213.34 

30,146.71 

7,040.37 

364.33 

891.12 

200.65 

538.71 

5,268.84 

868.91 
591.99 

229.75 
2,407.25 

16,929.82 

414.88 

7,991.10 

149.79 

1,874.34 
855.97 

1,530.14 
749.36 

253.46 

583.02 

12,245.73 

138.77 

809.67 

906.63 

279.51 

52.26 

3,017.37 

168.19 

17,530.39 

901.36 



$ 
35.50 
33.00 
41.40 
33.75 

39.10 
39.40 
43.40 
31.00 

43.20 
46.10 
38.50 
33.90 

47.25 
43.10 
42.10 
46.40 

42.25 
43.20 
36.00 
45.50 

41.30 
41.50 
41.60 

41.50 

46.20 
40.00 
39.10 
44.00 

40.00 
38.50 
44.20 
47.20 

43.10 
35.60 
37.00 
42.60 



% 
35.77 
68.04 
40.67 
32.98 

39.22 
38.69 
41.99 

28.09 

42.05 
45.22 
38.92 
33.55 

45.80 
42.30 
40.92 
41.78 

41.63 
42.75 
27.35 
44.47 

38.12 
40.47 
42.14 
40.31 

45.54 
38.59 
38.46 
43.43 

39.28 
37.81 
43.95 
47.04 

41.65 
35.89 
35.01 
43.74 



112 



Appendix II — Financial 



SOUTHERN ONTARIO 

STATEMENT OF THE ALLOCATION 

for the Year 



Municipality 



Power and energy 








supplied during year 








(principal bases 






Cost of 


of cost allocation) 










Power 










purchased, 




Provision 






operating 




for 






costs, and 


Frequency 


stabilization 


Average of 




fixed 


standardi- 


of rates and 


monthly 




charges 


zation 


contingencies 


peak loads 


Energy 


(Note 2) 


(Note 3) 


(Note 4) 




megawatt- 








kw 


hours 


$ 


$ 


$ 


531.4 


2,580.1 
28,156.9 


20,601 
227,123 




531 


5,883.2 




5,883 


274.1 


1,071.2 


10,745 


1,370 


274 


304.4 


1,381.0 
1,023.8 


13,200 
8,785 




304 


235.9 


1,180 


236 


155.1 


701.4 


6,035 


775 


155 


454.7 


2,094.4 


18,299 




455 


282.2 


1,000.4 


10,902 


1,411 


282 


3,086.1 


16,416.0 


109,244 




3,086 


221.7 


988.8 


8,613 


1,109 


222 


2,239.9 


11,083.1 


81,945 


11,199 


2,240 


890 


4,680 7 


37,553 
13,194 




890 


346.1 


1,584.0 


1,731 


346 


352.7 


1,431.6 


13,293 


1,763 


353 


1,438.0 


6,413.6 


55,981 


7,190 


1,438 


225.1 


939.2 


9,061 


1,126 


225 


218.0 


914.0 


7,950 


1,090 


218 


534.2 


2,216.4 


22,748 




534 


7,809.7 


39,508.2 


257,542 


39,048 


7,810 


3,186.8 


16,029.2 


121,281 


15,934 


3,187 


1,521.2 


6,379.8 


59.083 
16,120 




1,521 


366.2 


1,596.0 


1,831 


366 


32,692.8 


182,907.1 


1,110,080 


163,464 


32,693 


543.8 


2,536.0 


20,493 




544 


3,613.3 


16,813.3 


132,797 


18,067 


3,613 


551.0 


2,664.0 


22 199 




551 


162.8 


576.6 


6,593 
31,635 




163 


774.7 


3,480.2 


3,873 


775 


360.4 


1,612.0 


13,797 


1,802 


360 


361.1 


1,798.4 


14,417 


1,806 


361 


58.3 


199.4 


2,208 


291 


58 


535.3 


2,491.8 


21,544 




535 


1,406.9 


7,258.4 


51,988 


7,035 


1,407 


104,611.8 


605,122.2 


3,620,765 


523,059 


104,612 


2,029.9 


9,446.4 


81,247 


10,149 


2,030 


3,429.2 


14,481.7 


123,436 


17,146 


3,429 



Coldwater 

Collingwood . . . 

Comber 

Cookstown. . . . 

Cottam 

Courtright 

Creemore 

Dashwood 

Deep River. . . . 

Delaware 

Delhi 

Deseronto 

Dorchester. . . . 

Drayton 

Dresden 

Drumbo 

Dublin 

Dundalk 

Dundas 

Dunnville 

Durham 

Dutton 

East York Twp 
Eganville 

Elmira 

Elmvale 

Elmwood 

Elora 

Embro 

Erieau 

Erie Beach. . . . 
Erin 

Essex 

Etobicoke Twp. 

Exeter 

Fergus 



Southern Ontario System — Cost of Primary Power 



113 



SYSTEM 



OF THE COST OF PRIMARY POWER 
Ended December 31, 1960 













Annual rates on 












a kilowatt basis 


primary power 


















Amounts 










Credit 




billed 








Provision 


resulting 




for primary 








for 


from 




power 


Balance 






nuclear 


matured 


Total cost 


(municipalities 


credited 






research 


sinking fund 


of 


at interim 


or 






(Note 5) 


(Note 1) 


primary power 


rates) 


charged 


Interim 


Actual 


$ 


$ 


$ 


$ 


$ 


$ 


$ 


48 


824 


20,356 


21,361.31 


1,005.31 


40.20 


38.31 


532 


16,565 


216,973 


229,442.87 


12,469.87 


39.00 


36.88 


23 


154 


12,258 


12,815.35 


557.35 


46.75 


44.72 


27 


90 


13,441 


14,003.94 


562.94 


46.00 


44.16 


21 




10,222 
6,979 


10,287.04 
7,071.42 


65.04 
92.42 


43.60 
45.60 


43.33 


14 




45.00 


41 


1.118 


17,677 


18,642.02 


965.02 


41.00 


38.88 


23 


85 


12,533 


13,332.37 


799.37 


47.25 


44.41 


294 




112,624 


112,643.57 


19.57 


36.50 


36.49 


19 


18 


9,945 


10,063.69 


118.69 


45.40 


44.86 


205 




95,589 


98,330.51 


2,741.51 


43.90 


42.68 


84 




38,527 


37.380.35 


1,146.65 


42.00 


43.29 


30 


260 


15,041 


15,400.71 


359.71 


44.50 


43.46 


29 


84 


15,354 


15,729.32 


375.32 


44.60 


43.53 


126 


384 


64,351 


66,866.26 


2,515.26 


46.50 


44.75 


19 


158 


10,273 


10,636.38 


363.38 


47.25 


45.64 


19 


45 


9,232 


9,440.86 


208.86 


43.30 


42.35 


46 




23,328 


24,038.27 


710.27 


45.00 


43.67 


725 


4,024 


301,101 


304,576.71 


3,475.71 


39.00 


38.55 


295 


430 


140,267 


143,405.64 


3,138.64 


45.00 


44.01 


130 




60,734 


62,368.17 


1,634.17 
506.80 


41.00 


39.93 


32 


180 


18,169 


18,675.80 


51.00 


49.61 


3,184 




1,309,421 


1,304,441.06 


4,979.94 


39.90 


40.05 


49 




21,086 


21,100.09 


14.09 


38.80 


38.78 


323 


2,013 


152,787 


156,457.35 


3,670.35 


43.30 


42.28 


50 


1,538 


21,262 


22,317.18 


1,055.18 


40.50 


38.59 


13 




6,769 


6,738.90 


30.10 


41.40 


41.58 


69 


2,124 


34,228 


35,443.67 


1,215.67 


45.75 


44.18 


32 


892 


15,099 


15,765.32 


666.32 


43.75 


41.90 


?3 




16,617 


17,243.32 
2,608.19 


626.32 


47.75 


46.02 


5 




2,562 


46.19 


44.75 


43.95 


18 




22,127 


22.591.41 
62,958.03 


464.41 


42.20 


41.34 


132 


876 


59,686 


3,272.03 


44.75 


42.42 


10,355 


519 


4,258,272 


4,393,695.60 


135,423.60 


42.00 


40.71 


181 


279 


93,328 


96,421.05 


3,093.05 


47.50 


45.98 


294 


1,732 


142,573 


146,770.48 


4,197.48 


42.80 


41.58 



114 



Appendix II — Financial 



SOUTHERN ONTARIO 

STATEMENT OF THE ALLOCATION 

for the Year 



Municipality 



Power and energy 

supplied during year 

(principal bases 

of cost allocation) 



Average of 

monthly 
peak loads 



Energy 



Cost of 



Power 

purchased, 

operating 

costs, and 

fixed 

charges 

(Note 2) 



Frequency 
standardi- 
zation 
(Note 3) 



Provision 

for 

stabilization 

of rates and 

contingencies 

(Note 4) 



Finch 

Flesherton . . . 

Fonthill 

Forest 

Forest Hill . . 
Frankford . . . 

Gait 

Georgetown . 

Glencoe 

Goderich . . . . 
Grand Bend . 
Grand Valley 

Granton 

Gravenhurst . 
Grimsby. . . . 
Guelph 

Hagersville . . 
Hamilton. . . . 
Hanover. . . . 
Harriston. . . 

Harrow 

Hastings. . . . 

Havelock 

Hawkesbury. 

Hensall 

Hespeler. . . 

Highgate 

Holstein 

Huntsville. . . 
Ingersoll. . . . 

Iroquois 

Jarvis 

Kemptville . 
Kincardine. . 
Kingston 
Kingsville. . . 



kw 

263.8 

373.4 

1,079.1 

1,201.7 

12,645.0 

645.8 

23,405.3 

6,996.3 

541.4 

5,451.3 

737.6 

424.3 

104.8 

2,393.7 

2,469.7 

33,507.5 

1,600.3 

311,609.6 

3,782.7 

1,201.5 

1,276.6 
433.5 
501.0 

2,852.1 

717.4 

5,181.0 

190.6 

111.5 

2,420.5 

5,127.6 

703.3 

333.9 

1,488.8 

2,052.9 

36,406.0 

1,653.9 



megawatt- 
hours 
1,043.2 
1,438.0 
5,536.0 
7,095.8 

69,951.1 

3,252.0 

114,659.6 

38,282.9 

2,516.0 

26,907.6 

3,315.2 

1,765.5 

441.8 

12,052.2 

13,154.0 

172.175.2 

6,698.4 

1,945,085.9 

15,771.7 

5,951.8 

6,118.6 

1,977.2 

2,510.8 

15,236.8 

3,172.8 

25,108.0 

649.1 

394.0 

13,270.9 

25,230.3 

3,500.8 

1,563.2 

7,125.5 

10,845.0 

206,323.9 

8,089.0 



10,058 
13.353 
39,851 
51,308 

425,576 

23,638 

758,424 

251,569 

21,976 

203,812 

29,250 

17,529 

4,050 

90,709 

94,373 

1,087,493 

60,064 

10,832,692 

129,703 

46,308 

50,797 
16,312 
19,715 
95,594 

28,164 

175,025 

7,279 

4,339 

95,677 

186,875 

26,179 

13,262 

60,005 

86,148 

1,231,239 

59,775 



5,396 
6,008 



63,225 



117,027 
34,981 

2,707 

27,257 

3,688 



524 



12,348 
167,538 



8,001 
1,308,867 



6,383 



3,587 

25,905 

953 



25,638 
1,669 



8,270 



264 

373 

1.079 

1.202 

12,645 

646 

23,405 

6,996 

541 
5.451 

737 
424 

105 

2,394 

2,470 

33.507 

1.600 
311.610 

3.783 
1.201 

1,277 
434 
501 

2,852 

717 

5,181 

191 

112 

2,421 

5,128 

703 

334 

1,489 

2.053 

36.406 

1,654 



Southern Ontario System — Cost of Primary Power 



15 



SYSTEM 



OF THE COST OF PRIMARY POWER 
Ended December 31, 1960 



primary power 


Amounts 

billed 

for primary 

power 

(municipalities 

at interim 

rates) 


Balance 
credited 

or 
charged 


Annual rates on 
a kilowatt basis 


Provision 

for 
nuclear 
research 
(Note 5) 


Credit 
resulting 

from 

matured 

sinking fund 

(Note 1) 


Total cost 

of 

primary power 


Interim 


Actual 


$ 
22 


$ 


$ 

10.344 
13,757 
46.427 

58,438 

502,67(1 

24,344 

887,373 

289.598 

25.253 

229.709 

33.733 

17.989 

4,614 

93.324 

109,426 

1,277,003 

67.679 

12,425.338 

133,808 

53.205 

58.280 
16,785 
20,262 
98.717 

32.430 

204.355 

8,354 

4.460 

98.332 

212.167 

26,947 

15.295 

61,629 

88,395 

1.271.212 

68.903 


$ 
10.484.73 
14.448.66 
46.671.43 
61.284.58 

510.858.00 

23.508.03 

884.718.77 

295.243.53 

25.826.39 

245.310.02 

36.142.81 

18.882.84 

4,652.01 

94,792.17 

114.224.03 

1.273,285.64 

68,012.05 

12.526,707.63 

138,068.25 

53.829.05 

59.361.92 
17.339.34 
21.040.25 
98.968.14 

33.429.29 

206,720.91 

8,842.68 

4,740.15 

102,630.94 

216,898.19 

29.892.01 

15.727.11 

60.742.70 

95,871.59 

1.270,570.00 

70,124.65 


$ 

140.73 

691.66 

244.43 

2,846.58 

8,187.00 

835.97 

2.654.23 

5,645.53 

573.39 

15,601.02 

2,409.81 

893.84 

38.01 
1,468.17 
4,798.03 
3,717.36 

333.05 
101,369.63 

4,260.25 
624.05 

1,081.92 
554.34 
778.25 
251.14 

999.29 

2,365.91 

488.68 

280.15 

4,298.94 

4,731.19 

2,945.01 

432.11 

886.30 
7.476.59 

642.00 
1,221.65 


$ 
39.75 
38.70 
43.25 
51.00 

40.40 
36.40 
37.80 
42.20 

47.70 
45.00 
49.00 
44.50 

44.40 
39.60 
46.25 
38.00 

42.50 
40.20 
36.50 
44.80 

46.50 
40.00 


$ 
39.21 


31 




36.84 


101 




43.02 


120 
1 225 


200 


48.63 
39.75 


60 




37.70 


2.140 
674 

48 

501 

65 

36 


13,623 

4,622 

19 

7,312 

7 


37.91 
41.39 

46.64 
42.14 

45.73 
42.40 


9 

221 


74 


44.03 
38.99 


235 




44.31 


3.133 

137 

32,057 

322 


14,668 

2,123 
59,888 


38.11 

42.29 
39.87 
35.37 


111 

116 
39 


423 
293 


44.28 

45.65 
38.72 


46 




42.00 40.44 


271 




34.70 

46.60 
39.90 
46.40 
42.50 

42.40 
42.30 
42.50 
47.10 

40.80 
46.70 
34.90 
42.40 


34.61 


63 

471 

15 

9 


101 

2,227 

84 


45.20 
39.44 
43.83 
40.00 


234 




40.62 


469 
65 


5,943 


41.38 

38.32 


30 




45.81 


135 




41.40 


194 




43.06 


3,567 




34.92 


151 


947 


41.66 



16 



Appendix II — Financial 



SOUTHERN ONTARIO 

STATEMENT OF THE ALLOCATION 

for the Year 



Municipality 



Power and energy 

supplied during year 

(principal bases 

of cost allocation) 



Average of 

monthly 
peak loads 



Energy 



Cost of 



Power 

purchased, 

operating 

costs, and 

fixed 

charges 

(Note 2) 



Frequency 
standardi- 
zation 
(Note 3) 



Provision 

for 

stabilization 

of rates and 

contingencies 

(Note 4) 



Kirkfield 

Kitchener. . . 

Lakefield 

Lambeth 

Lanark 

Lancaster. . . 
Leamington . 
Lindsay 

Listowel 

London 

London Twp 
Long Branch 

L'Orignal 

Lucan 

Lucknow. . . . 
Lynden 

Madoc 

Magnetawan 
Markdale . . . 
Markham. . . 

Marmora. . . . 
Martintown. 
Maxville. . . . 
Meaford 

Merlin 

Merrickville . 
Merritton. . . 
Midland . . . . 

Mildmay. . . . 
Millbrook. . . 

Milton 

Milverton. . . 

Mimico 

Mitchell 

Moorefield . . . 
Morrisburg. . 



kw 

76.6 

64,253.1 

1,194.2 

823.0 

296.2 

259.9 

5,614.9 

7,996.2 

2,961.1 

65,252.8 

1,561.4 

6,322.1 

337.5 
540.1 
696.9 
276.4 

804.0 

78.3 

643.2 

2,589.2 

668.8 

152.6 

420.4 

2,559.0 

271.5 

413.3 

17,903.9 

7,476.2 

533.0 

420.1 

3,748.2 

846.5 

7,974.8 

1,819.0 

205.9 

1,214.4 



megawatt- 
hours 

348.2 

339,401.3 

6,047.8 

3,708.0 

1,381.0 

1,196.9 

29,655.2 

44,924.5 

13,718.4 

384,303.7 

6,989.7 

33,202.9 

1,622.6 
2,438.4 
3,173.6 
1,253.6 

4,020.0 

342.8 

2,996.0 

12,623.5 

3,335.3 

578.4 

1,731.5 

13,137.5 

1,238.4 

2,072.1 

110,515.2 

37,490.2 

2,152.6 

2,004.7 

19,481.8 

3,371.2 

44,583.5 

8,815.3 

880.0 

6,296.0 



$ 

3,188 

1,936,479 

42,707 

31,053 

11,494 

10,181 

212,634 

310,390 

106,375 

2,239,112 

54,994 

220,600 

13,147 
21,834 
28,616 
10,593 

32,863 

3,249 

26,461 

98,683 

27,773 

5,551 

17,886 

106,728 

10,568 

15,875 

631,410 

267,404 

20,080 

17,651 

141,555 

33,243 

275,041 

66,628 

7,681 

45,242 



$ 

321,265 
4,115 



28,075 



14,805 

326,264 

7,807 

31,611 



2,700 
1,382 



1,358 
89,519 



18,741 
4,233 

39,874 
9,095 
1,029 



$ 


77 


64,253 


1,194 


823 


296 


260 


5,615 


7,996 


2,961 


65,253 


1,561 


6,322 


338 


540 


697 


276 


804 


78 


643 


2,589 


669 


153 


420 


2,559 


272 


413 


17,904 


7,476 


533 


420 


3,748 


847 


7,975 


1,819 


206 


1,214 



Southern Ontario System — Cost of Primary Power 



117 



SYSTEM 



OF THE COST OF PRIMARY POWER 
Ended December 31, 1960 













Annual rates on 


primary power 










a kilowatt basis 








Amounts 










Credit 




billed 








Provision 


resulting 




for primary 








for 


from 




power 


Balance 






nuclear 


matured 


Total cost 


(municipalities 


credited 






research 


sinking fund 


of 


at interim 


or 






(Note 5) 


(Note 1) 


primary power 


rates) 


charged 


Interim 


Actual 


$ 


$ 


$ 


$ 


$ 


$ 


$ 


7 


89 


3.183 


3,386.09 


203.09 


44.20 


41.55 


6,086 


28,447 


2,299,636 


2,338,811.33 


39,175,33 


36.40 


35.79 


111 




44,012 


43,827.15 


184.85 


36.70 


36.85 


73 


37 


36,027 


36,703.95 


676.95 


44.60 


43.78 


27 




11,817 
10,464 


11,994.77 
10,523.94 


177.77 
59.94 


40.50 
40.50 


39.90 


23 




40.26 


532 


1,116 


245,740 


251,546.04 


5.806.04 


44.80 


43.77 


780 




319,166 


316,648.86 


2,517.14 


39.60 


39.91 


265 


799 


123,607 


126,735.15 


3,128.15 


42.80 


41.74 


6,517 


62,479 


2,574,667 


2,629,688.51 


55,021.51 


40.30 


39.46 


139 




64,501 


65,576.70 


1,075.70 


42.00 


41.31 


597 




259,130 


265,526.10 


6,396.10 


42.00 


40.99 


31 




13.516 


13,599.57 


83.57 


40.30 


40.05 


48 


330 


24,792 


25,384.32 


592.32 


47.00 


45.90 


62 




29,375 


31,707.45 


2,332.45 


45.50 


42.15 


24 


169 


12,106 


12,232.53 


126.53 


44.25 


43.80 


74 




33,741 


33,567.00 


174.00 


41.75 


41.97 


7 




3,334 


3,587.67 


253.67 


45.80 


42.58 


57 




27,161 


27,723.00 


562.00 


43.10 


42.23 


236 


37 


114,417 


117,550.46 


3,133.46 


45.40 


44.19 


61 




28,503 


30,765.94 


2,262.94 


46.00 


42.62 


13 




5,717 


5,607.45 


109.55 


36.75 


37.46 


36 




18,342 


17,970.68 


371.32 


42.75 


43.63 


239 




109,526 


113,105.98 


3,579.98 


44.20 


42.80 


24 




12,222 


12,487.84 


265.84 


46.00 


45.02 


39 




16,327 


16,368.00 


41.00 


39.60 


39.50 


1,831 




740,664 


732,269.18 


8,394.82 


40.90 


41.37 


692 


11,063 


264,509 


269,144.70 


4,635.70 


36.00 


35.38 


45 




20,658 


21,319.67 


661.67 


40.00 


38.76 


38 




18,109 


18,066.09 


42.91 


43.00 


43.11 


353 


4,795 


159,602 


163,421.50 


3,819.50 


43.60 


42.58 


71 


515 


37,879 


38,260.68 


381.68 


45.20 


44.75 


776 


1,522 


322,144 


325,768.90 


3,624.90 


40.85 


40.40 


166 


1,685 


76,023 


79.307.32 


3,284.32 


43.60 


41.79 


17 


48 


8,885 


8,957.42 


72.42 


43.50 


43.15 


115 




46,571 


49,788.36 


3,217.36 


41.00 


38.35 









118 



Appendix II — Financial 



SOUTHERN ONTARIO 

STATEMENT OF THE ALLOCATION 

for the Year 



Municipality 



Power and energy 

supplied during year 

(principal bases 

of cost allocation) 



Average of 

monthly 
peak loads 



Cost of 



Energy 



Power 

purchased, 

operating 

costs, and 

fixed 

charges 

(Note 2) 



Frequency 
standardi- 
zation 

(Note 3) 



Provision 

for 

stabilization 

of rates and 

contingencies 

(Note 4) 



Mount Brydges 

Mount Forest 

Napanee 

Neustadt 

Newboro 

Newburgh 

Newbury 

Newcastle 

New Hamburg 

Newmarket 

New Toronto 

Niagara 

Niagara Falls 

North York Twp 

Norwich 

Norwood 

Oakville 

Oakville-Trafalgar 

Oil Springs 

Omemee 

Orangeville 

Orillia 

Orono 

Oshawa 

Ottawa 

Otterville 

Owen Sound 

Paisley 

Palmerston 

Paris 

Parkhill 

Parry Sound 

Penetanguishene 

Perth 

Peterborough 

Petrolia 

Petrolia Waterworks 



kw 

336.6 
1.834.9 
3,269.8 

271.8 

92.9 
241.7 
103.9 
826.1 

1,279.3 
6.086.1 

27,375.2 
1,585.8 

15,869.7 

149,524.5 

850.1 

545.5 

4,505.8 

13,779.2 

243.5 

388.4 

2.947.3 

5.224.4 

460.7 

62.910.4 

149,454.9 

370.8 

11,678.1 

427.3 

1,068.5 

3,472.4 

769.6 

1,808.9 

2,544.1 

3,739.4 

35,340.8 

1,401.3 

137.3 



megawatt- 
hours 
1,488.8 
8,308.8 
15,980.2 
1,045.6 

395.2 
1.114.8 

467.8 
3.833.5 

5.930.4 

30.650.4 

151.450.6 

8.752.4 

86,221.3 

839,919.7 

4,305.6 

2.585.2 

24.251.2 

80.221.8 

1.363.2 

1,816.9 

14,542.5 

17,708.4 

2,145.9 

338,901.8 

805,364.0 

1,689.6 

58,350.7 

1,961.8 

5.280.5 
16,394.8 

3,546.4 
10,552.6 

13,734.2 

18.528.6 

207.969.3 

7,355.9 

660.7 



$ 
12,758 
71,477 

126,848 
9,844 

3,424 

9,732 

4,204 

29,430 

49,417 
212,119 
948,896 

59,798 

539,177 

5,141,295 

34,771 

23,159 

154,933 

493,737 

10,302 

15,977 

120,540 
190,334 

17.552 
2.078.462 

4.960.044 

13,699 

408,248 

16,235 

34,962 

115,544 

31,000 

73.832 

96,180 

142,896 

1,237,810 

58,508 

5.228 



1.683 



6.396 

30.431 

136,876 

7,929 

79,348 

747,623 

4,250 



22.529 

68,896 

1,218 



1,854 



5,342 
17.362 
3.848 



7,007 
686 



337 
1,835 
3.270 

272 

93 
242 
104 
826 

1,279 

6,086 

27,375 

1.586 

15,870 

149,525 

850 

546 

4,506 

13,779 

244 

388 

2,947 

5,224 

461 

62,910 

149,455 

371 

11,678 

427 

1,069 

3,472 

770 

1,809 

2,544 

3,739 

35,341 

1,401 

137 



Southern Ontario System — Cost of Primary Power 



119 



SYSTEM 

OF THE COST OF PRIMARY POWER 
Ended December 31, 1960 



primary power 



Provision 

for 

nuclear 

research 

(Note 5) 



Credit 
resulting 

from 

matured 

sinking fund 

(Note 1) 



Total cost 

of 

primary power 



Amounts 

billed 

for primary 

power 

(municipalities 

at interim 

rates) 



Balance 
credited 

or 
charged 



Annual rates on 
a kilowatt basis 



Interim 



Actual 



30 
162 

299 
23 



21 
9 

74 

114 

563 

2,651 

153 

1,524 

14,588 

79 

49 

431 
1,369 

24 
34 

271 

410 

41 

6,015 

14,292 

32 

1,077 

38 

98 
312 

68 
180 

244 

343 

3,528 

133 

13 



1,840 

4 

20,994 

300 

5,608 

3 

1,828 



205 



234 

3,284 

40 



8,366 



841 



$ 

14,764 

73,474 

130,417 

10,139 

3,525 

9,995 

4,837 

30,330 

55,366 

249,195 

1,094,804 

69,166 

630,311 

6,053,028 

38,122 

23,754 

182,399 

577,781 

11,583 

16,399 

123,758 

195,968 

18,054 

2,147,387 

5,123,745 

15,893 

421,003 

16,700 

41,237 

133,406 

35,646 

75,821 

90,602 

146,978 

1,276,679 

66,208 

6,064 



$ 

15,012.75 

75,047.06 

134,877.87 

10,519.99 

3,464.23 

9,788.86 

5,092.74 

30,235.29 

56,032.62 

252.571.76 

1,111.431.07 

70,249.84 

634,789.34 

6,152,932.15 

38,083.73 

24,683.13 

184,286.20 

586,995.00 

12,416.40 

16,313.85 

131,893.55 

207,930.82 

17,599.39 

2,176,699.00 

5,111,358.45 

16,239.22 

432,087.85 

17,132.75 

42,740.66 
135,769.86 
36,400.51 
80,674.70 

91,586.10 

142,846.69 

1,272,270.30 

67,262.00 

6,589.20 



$ 

248.75 
1,573.06 
4,460.87 

380.99 

60.77 
206.14 

255.74 
94.71 

666.62 

3,376.76 

16,627.07 

1,083.84 

4,478.34 

99,904.15 

38.27 

929.13 

1,887.20 

9,214.00 

833.40 

85.15 

8,135.55 

11,962.82 

454.61 

29,312.00 

12,386.55 
346.22 

11,084.85 
432.75 

1,503.66 

2,363.86 

754.51 

4,853.70 

984.10 
4,131.31 
4,408.70 
1,054.00 

525.20 



$ 

44.60 
40.90 
41.25 
38.70 

37.30 
40.50 
49.00 
36.60 

43.80 
41.50 
40.60 
44.30 

40.00 
41.15 
44.80 
45.25 

40.90 
42.60 
51.00 
42.00 

44.75 
39.80 
38.20 
34.60 

34.20 
43.80 
37.00 
40.10 

40.00 
39.10 
47.30 
44.60 

36.00 
38.20 
36.00 
48.00 
48.00 



$ 
43.86 
40.04 
39.89 
37.30 

37.94 
41.35 
46.55 
36.71 

43.28 
40.94 
39.99 
43.62 

39.72 
40.48 
44.84 
43.55 

40.48 
41.93 

47.57 
42.22 

41.99 
37.51 
39.19 
34.13 

34.28 
42.86 
36.05 
39.08 

38.59 
38.42 
46.32 
41.92 

35.61 
39.31 
36.12 
47.25 
44.17 



120 



Appendix II — Financial 



SOUTHERN ONTARIO 



STATEMENT OF THE ALLOCATION 

for the Year 





Power and energy 

supplied during year 

(principal bases 

of cost allocation) 


Cost of 


Municipality 


Average of 

monthly 
peak loads 


Energy 


Power 

purchased, 

operating 

costs, and 

fixed 

charges 

(Note 2) 


Frequency 
standardi- 
zation 
(Note 3) 


Provision 

for 

stabilization 

of rates and 

contingencies 

(Note 4) 




kw 

736.7 
3,410.3 

633.1 

4.025.4 

217.4 
5.543.2 
9,411.8 
1,385.9 

1.843.0 
1.110.7 
7,435.0 
1.157.6 

1.215.0 
234.1 
983.8 

3,172.6 

8,744.0 

45.5 

244.5 

315.7 

3,755.9 

529.3 

8,498.9 

1,294.0 

284.6 

5.898.9 
914.1 
385.8 

462.0 

99.8 

266.4 

41.058.5 

533.6 

466.7 

454.4 

9,890.4 


megawatt- 
hours 
3,888.4 
18,055.7 
2,801.6 
15,843.2 

980.6 

29,741.2 

68,621.4 

8,402.4 

10.024.8 
5,635.4 

38,452.6 
3,482.0 

5,827.2 

1.142.0 

5,225.6 

15,920.7 

42,752.5 

192.4 

1,068.4 

1.742.3 

17,255.0 
2,560.4 

42,736.8 
5,818.6 

1.239.6 

27,936.0 

4,346.3 

1,836.8 

2,123.2 

433.8 

1.245.5 

211.224.5 

2,482.6 

2,220.0 

1,815.5 

60.395.4 


$ 

27,795 
130,377 

23,587 
129.425 

8.647 

200.273 

366,841 

54,088 

68,161 

47,354 

248,022 

39,399 

49.840 

9,284 

40.951 

122.278 

293.556 

1.812 

9.479 

11,666 

138,686 
18,508 

321,661 
51,635 

11,622 

211,498 

32,533 

16,514 

18,104 

4,096 

9,480 

1,353,813 

19,604 

17.751 

18,575 

345,792 


$ 


$ 

737 






3,410 


Plattsville 


3,166 
20.127 

1.087 
27.716 
47.059 

6,929 

9.215 


633 


Point Edward 


4,025 


Port Burwell 


217 


Port Colborne 


5,543 


Port Credit 


9,412 


Port Dalhousie 


1,386 


Port Dover 


1,843 


Port Elgin 


1,111 


Port Hope 




7,435 


Port McNicoll. . 




1,158 


Port Perry 




1,215 


Port Rowan 


1.171 
4.919 


234 


Port Stanley 


984 


Prescott 


3,173 


Preston 


43,720 


8,744 


Priceville 


45 


Princeton 


1.222 
1.579 


245 


Queenston 


316 


Renfrew 


3,756 


Richmond 




529 


Richmond Hill 


42.494 
6,470 


8,499 


Ridgetown 


1,294 


Ripley 


285 


Riverside 


29,495 


5,899 


Rockland 


914 




1,929 

2,310 


386 




462 




100 






266 


St. Catharines 


205.292 

2,668 

2,334 

2.272 

49.452 


41,059 


St. Clair Beach 


534 




467 




454 


St. Mary's 


9,890 







Southern Ontario System — Cost of Primary Power 



121 



SYSTEM 



OF THE COST OF PRIMARY POWER 
Ended December 31, 1960 



primary power 


Amounts 

billed 

for primary 

power 

(municipalities 

at interim 

rates) 


Balance 
credited 

or 
charged 


Annual rates on 
a kilowatt basis 


Provision 

for 
nuclear 
research 
(Note 5) 


Credit 
resulting 

from 

matured 

sinking fund 

(Note 1) 


Total cost 

of 

primary power 


Interim 


Actual 


$ 
70 


$ 


$ 

28,602 
134,110 

26,133 
153,672 

9,963 

234.061 

423,853 

62,543 

79,396 

48.568 

256,154 

40,185 

51,165 

10,711 

44,944 

122,740 

339,467 

1,861 

10,596 

13.592 

142,776 
19,085 

373,440 
59,217 

11,931 

247,423 

33,530 

18,208 

20,821 

4,205 

9,770 

1,604.005 

22.854 

20,488 

21,214 

401,236 


$ 

28,729.42 
131,297.84 

27,383.02 
160,009.68 

10,596.20 
235,587.78 
435,293.44 

62.709.71 

80,356.24 

50,257.66 

275,096.26 

40,864.45 

52,610.60 

11,355.48 

45,154.50 

120,558.79 

343.200.03 
2.046.75 
11.001.40 
13.733.72 

138,967.40 
19,373.60 

383,299.64 
62,437.51 

12,876.27 

254,831.40 

33,272.65 

18,361.69 

22,175.20 

4,249.74 

9,671.56 

1.609,492.88 

23,105.97 

20,722.96 

21,176.21 

418,363.93 


% 

127.42 
2,812.16 
1,250.02 
6,337.68 

633.20 

1,526.78 

11,440.44 

166.71 

960.24 

1,689.66 

18,942.26 

679.45 

1,445.60 
644.48 
210.50 

2,181.21 

3,733.03 
185.75 
405.40 
141.72 

3,808.60 

288.60 

9,859.64 

3,220.51 

945.27 

7,408.40 

257.35 

153.69 

1,354.20 
44.74 
98.44 

5,487.88 

251.97 

234.96 

37.79 

17,127.93 


$ 
39.00 
38.50 
43.25 
39.75 

48.75 
42.50 
46.25 
45.25 

43.60 
45.25 
37.00 
35.30 

43.30 
48.50 
45.90 
38.00 

39.25 
45.00 
45.00 
43.50 

37.00 
36.60 
45.10 
48.25 

45.25 
43.20 
36.40 
47.60 

48.00 
42.60 
36.30 
39.20 

43.30 
44.40 
46.60 
42.30 


$ 

38.82 


323 




39.32 


56 
336 

19 
529 


1,309 
241 

7 


41.28 
38.18 

45.83 
42.22 


1,052 
140 


511 


45.03 
45.13 


177 




43.08 


103 




43.73 


697 




34.45 


88 
110 


460 


34.71 
42.11 


22 




45.75 


93 
293 

799 
4 


2,003 
3,004 

7,352 


45.68 
38.69 

38.82 
40.90 


21 
31 


371 


43.34 
43.05 


334 




38 01 


48 




36 06 


786 




43 94 


113 

24 


295 


45.76 
41 92 


531 




41 94 


83 




36 68 


35 

41 
9 


656 
96 


47.20 

45.07 
42 13 


24 




36 67 


3,841 




39 07 


48 




42 83 


42 

37 

1,006 


106 

124 

4,904 


43.90 
46.69 
40.57 



122 



Appendix II — Financial 



SOUTHERN ONTARIO 

STATEMENT OF THE ALLOCATION 

for the Year 



Municipality 



Power and energy 

supplied during year 

(principal bases 

of cost allocation) 



Average of 

monthly 
peak loads 



Energy 



Cost of 



Power 

purchased, 

operating 

costs, and 

fixed 

charges 

(Note 2) 



Frequency 
standardi- 
zation 
(Note 3) 



Provision 

for 

stabilization 

of rates and 

contingencies 

(Note 4) 



St. Thomas 

Sandwich East Twp. 
Sandwich West Twp 
Sarnia 

Scarborough Twp. . . 

Seaforth 

Shelburne 

Simcoe 

Smith's Falls 

Smithville 

Southampton 

Springfield 

Stamford Twp 

Stayner 

Stirling 

Stoney Creek 

Stouffville 

Stratford 

Strathroy 

Streetsville 

Sunderland 

Sundridge 

Sutton 

Swansea 

Tara . 

Tavistock 

Tecumseh 

Teeswater 

Thamesford 

Thamesville 

Thedford 

Thornbury 

Thorndale 

Thornton 

Thorold 

Tilbury 



kw 

13.612.2 

5,720.7 

10,559.1 

116,372.6 

120,599.7 

1,587.3 

763.5 

7,018.3 

6,780.8 
562.9 

1,038.4 
218.4 

15,137.6 

946.2 

826.4 

3,280.9 

1,749.8 
14,866.7 
3,294.6 
2,760.2 

392.5 

310.4 

917.8 

5,627.0 

395.8 

771.0 

1,263.0 

639.0 

645.7 
646.6 
392.3 
769.6 

235.9 

114.5 

10,811.8 

1.188.6 



megawatt- 
hours 
76,641.5 
29,460.2 
52,416.8 
920,753.0 

641,029.6 

7,229.7 

3,440.4 

36,898.0 

33,869.8 

2,330.4 

5,399.6 

960.4 

79,826.0 
4,692.0 
3,775.4 

16,416.6 

8,310.9 
77,999.3 
16,790.8 
13,819.3 

1,761.6 

1,572.0 

4,889.8 

33,449.8 

1,810.4 
3,844.0 
6,103.2 
2,946.0 

3,194.4 
2,773.3 
1,888.4 
3,667.2 

968.8 

474.2 

66,892.5 

5,309.0 



$ 

460,585 

206,761 

376.136 

4.421.532 

4.079,354 

51.006 

32,025 

237,323 

226,062 

21,583 

44,980 

7.740 

510.716 
37,605 
28,138 

118.503 

68,907 
489.276 
109,404 

98,146 

15,849 

13.021 

37,397 

197,877 

15,736 
30,062 
46,487 
26,754 

26.750 
26,350 
15,966 
31,616 

9,028 

4,292 

379,691 

47,657 



$ 
68,061 
28,603 
52,796 

581,863 

602,998 
7,937 



35,091 



2,815 

1,092 

75,688 



16,404 

8.749 
74,334 
16,473 
13,801 



4,589 
28.135 



3,855 
6,315 



3,228 
3.233 
1,962 



1,179 



54,059 
5,943 



$ 

13.612 
5,721 

10,559 
116,373 

120,600 

1,587 

764 

7.018 

6,781 
563 

1,038 
218 

15,138 

946 

826 

3,281 

1,750 

14,867 

3,294 

2.760 

393 

310 

918 

5,627 

396 

771 

1,263 

639 

646 
647 
392 
770 

236 

114 

10,812 

1,189 



Southern Ontario System — Cost of Primary Power 



123 



SYSTEM 



OF THE COST OF PRIMARY POWER 
Ended December 31, 1960 













Annual rates on 


primary power 










a kilowatt basis 








Amounts 










Credit 




billed 








Provision 


resulting 




for primary 








for 


from 




power 


Balance 






nuclear 


matured 


Total cost 


(municipalities 


credited 






research 


sinking fund 


of 


at interim 


or 






(Note 5) 


(Note 1) 


primary power 


rates) 


charged 


Interim 


Actual 


$ 


$ 


$ 


% 


$ 


$ 


$ 


1,329 


13.922 


529,665 


540,405.66 


10,740.66 


39.70 


38.91 


535 




241,620 


245,418.04 


3,798.04 


42.90 


42.24 


971 




440,462 


450,873.22 


10,411.22 


42.70 


41.71 


13,623 


4,637 


5,128.754 


5,149,489.03 


20.735.03 


44.25 


44.07 


11,457 


88 


4,814,321 


4,932.527.73 


118,206.73 


40.90 


39.92 


140 


3,653 


57,017 


57.934.94 


917.94 


36.50 


35.92 


67 




32,856 


35,500.43 


2,644.43 


46.50 


43.03 


664 


339 


279,757 


284,240.17 


4,483.17 


40.50 


39.86 


626 




233,469 
25,009 


233,258.65 
25,894.56 


210.35 
885.56 


34.40 
46.00 


34.43 


48 




44.43 


98 




46,116 
9,014 


47,248.70 
9.391.91 


1,132.70 
377.91 


45.50 
43.00 


44.41 


19 


55 


41.27 


1,432 


642 


602,332 


612,313.89 


9,981.89 


40.45 


39.79 


87 


1,576 


37,062 


38,605.64 


1,543.64 


40.80 


39.17 


73 




29,037 


29,748.60 


711.60 


36.00 


35.14 


303 




138,491 


143,045.42 


4,554.42 


43.60 


42.21 


158 




79,564 
568,123 


80,840.40 
576,828.60 


1,276.40 
8,705.60 


46.20 
38.80 


45.47 


1,404 


11,758 


38.21 


307 


3,909 


125,569 


128.491.05 


2,922.05 


39.00 


38.11 


255 




114,962 
13,986 


117.859.84 
16.798.97 


2,897.84 
2,812.97 


42.70 
42.80 


41.65 


35 


2,291 


35.63 


28 




13,359 

42,992 

232,203 


14,277.66 

44,052.00 

235.770.61 


918.66 
1.060.00 
3.567.61 


46.00 
48.00 
41.90 


43.04 


88 




46.84 


564 




41.27 


35 




16,167 

34,298 


17,116.55 
34,462.59 


949.55 
164.59 


43.25 
44.70 


40.85 


71 


461 


44.49 


115 




54,180 
27,450 

29,606 


55,317.95 
28,755.76 

30,669.17 


1,137.95 
1,305.76 

1,063.17 


43.80 
45.00 

47.50 


42.90 


57 




42.96 


59 


1.077 


45.85 


56 


98 


30,188 


30,648.84 


460.84 


47.40 


46.69 


36 




18,356 
32,455 


19,221.08 
33,863.86 


865.08 
1,408.86 


49.00 
44.00 


46.79 


69 




42.17 


20 


1,005 


9,458 


9,906.40 


448.40 


42.00 


40.09 


10 


16 


4,400 


4.431.50 


31.50 


38.70 


38.43 


1,108 




445,670 
54,728 


450.851.37 
56.754.86 


5,181.37 
2,026.86 


41.70 

47.75 


41.22 


104 


165 


46.04 



124 



Appendix II — Financial 

SOUTHERN ONTARIO 
STATEMENT OF THE ALLOCATION 

for the Year 



Municipality 



Power and energy 

supplied during year 

(principal bases 

of cost allocation) 



Average of 

monthly 
peak loads 



Energy 



Cost of 



Power 

purchased, 

operating 

costs, and 

fixed 

charges 

(Note 2) 



Frequency 
standardi- 
zation 
(Note 3) 



Provision 

for 

stabilization 

of rates and 

contingencies 

(Note 4) 



Tillsonburg 

Toronto 

Toronto Twp 

Tottenham 

Trafalgar Twp 

Trenton 

Tweed 

Uxbridge 

Vankleek Hill 

Victoria Harbour 

Walkerton 

Wallaceburg 

Wardsville • 

Warkworth 

Wasaga Beach 

Waterdown 

Waterford 

Waterloo 

Watford 

Waubaushene 

Welland 

Wellesley 

Wellington 

West Lome 

Weston 

Westport 

Wheatley 

Whitby 

Wiarton 

Williamsburg 

Winchester 

Windermere 

Windsor 

Wingham 

Woodbridge 

Woodstock 

Woodville 

Wyoming 

York Twp 

Zurich 

Total — Municipalities. . . . 



kw 

4,664.0 

571,659.1 

47,166.0 

364.1 

9,336.1 

14,866.2 

1,012.1 

1,522.9 

533.4 

335.4 

2,721.2 

7,364.4 

164.7 
247.2 
660.0 
950.2 

952.0 

15,457.5 

1,162.7 

289.0 

13,380.5 
388.7 
551.9 
915.6 

8,166.3 
346.9 

771.7 
10,129.3 

1,209.5 
205.5 

1.110.0 
125.0 

76,057.5 
2,114.9 
1,943.9 

16.991.9 

186.3 

357.6 

57,252.3 

371.9 



2,968,929.9 



megawatt- 
hours 
22,484.5 
3,354,932.0 
303.930.6 
1,783.6 

59,748.4 

85,890.2 

4,687.7 

7,533.6 

2,483.9 

1,522.4 

11,273.9 

43,676.8 

774.6 
1,013.1 
2,526.4 
4,780.8 

4,193.2 

81,609.0 

5,145.8 

1,301.6 

69,921.5 
1,611.2 
2,524.1 
3,897.6 

44,564.7 
1,636.0 
3,429.3 

53.574.3 

6,386.4 
923.0 

5,736.4 
536.4 

389,650.7 

10,635.5 

9,543.6 

93,981.5 

862.8 

1,562.0 

333,903.1 

1,621.2 



$ 

150,395 

19,395,361 

1,725.372 

15,199 

347,755 

504,008 

37,034 

63,428 

19,260 

13,968 

91,990 

259,183 

6,675 

9,061 

25,890 

33,945 

34,918 

465,767 

46,265 

12,004 

448,761 
14,561 
23,014 
36,217 

282,118 
13,222 
30,873 

340,781 

52.195 
8,530 

44,999 
4,881 

2,503,722 

82,046 

72.749 

570,317 

7.958 

14,337 

1,943,768 

14,955 



23,320 

2,858,297 

235,830 



46,680 



36,822 
824 



4,751 

4,760 

77,287 
5,814 



66,902 
1,944 



4,578 

40,831 

3,859 



380,287 



9,720 
84,959 



1.788 

286,262 

1,859 



16,828,812.9 



102,566,485 



11,809,145 



Southern Ontario System — Cost of Primary Power 

SYSTEM 

OF THE COST OF PRIMARY POWER 

Ended December 31, 1960 



125 













Annual rates on 


primary power 










a kilowatt basis 








Amounts 










Credit 




billed 








Provision 


resulting 




for primary 








for 


from 




power 


Balance 






nuclear 


matured 


Total cost 


(municipalities 


credited 






research 


sinking fund 


of 


at interim 


or 






(Note 5) 


(Note 1) 


primary power 


rates) 


charged 


Interim 


Actual 


$ 


$ 


$ 


$ 


$ 


$ 


$ 


423 


4,961 


173.841 


176,765.92 


2,924.92 


37.90 


37.27 


56,996 


220,600 


22.661.713 


23.009.278.11 


347,565.11 


40.25 


39.64 


4,933 


1,095 


2.012,206 


2.049,361.25 


37,155.25 


43.45 


42.66 


33 


42 


15.554 


16,131.11 


577.11 


44.30 


42.72 


973 




404,744 


401,452.66 


3,291.34 


43.00 


43.35 


1,471 




520,345 


516,599.29 


3,745.71 


34.75 


35.00 


90 




38,136 


37,952.20 


183.80 


37.50 


37.68 


140 




65.091 


66,397.37 


1,306.37 


43.60 


42.74 


48 




19,841 


21,604.09 


1,763.09 


40.50 


37.20 


30 


682 


13.651 


14.254.14 


603.14 


42.50 


40.70 


232 




94,943 


102,724.99 


7,781.99 


37.75 


34.89 


738 


1,463 


302.644 


303.412.95 


768.95 


41.20 


41.10 


15 




7,679 


8,113.12 


434.12 


49.25 


46.62 


20 




9,328 


9,515.92 


187.92 


38.50 


37.73 


54 




26,604 


27,718.60 


1,114.60 


42.00 


40.31 


88 


893 


38,841 


39,146.17 


305.17 


41.20 


40.88 


83 


239 


40.474 


41,126.40 


652.40 


43.20 


42.51 


1,464 


5,741 


554,234 


559.562.39 


5,328.39 


36.20 


35.86 


102 


103 


53.241 


54,182.99 


941.99 


46.60 


45.79 


25 


344 


11,974 


11,934.34 


39.66 


41.30 


41.43 


1.261 


5,582 


524,722 


527,192.69 


2,470.69 


39.40 


39.22 


33 


213 


16,714 


16,907.37 


193.37 


43.50 


43.00 


49 




23,615 


23,070.14 
44,864.82 


544.86 


41.80 


42.79 


79 


148 


41,641 


3,223.82 


49.00 


45.48 


786 


5,477 


326,424 


333,184.70 


6,760.70 


40.80 


39.97 


31 




13,600 
35,570 


13,319.36 


280.64 


38.40 


39.20 


67 




36,426.20 


856.20 


47.20 


46.09 


960 




351,870 


352,498.77 


628.77 


34.80 


34.74 


,., 




53,519 


54,789.99 


1,270.99 


45.30 


44.25 


18 


62 


8,692 


9,039.81 


347.81 


44.00 


42.30 


104 


1,686 


44,527 


45,510.70 


983.70 


41.00 


40.11 


11 




5.017 


5.114.20 


97.20 


40.90 


40.14 


7,102 


61,981 


2.905,188 


2,947,229.10 


42,041.10 


38.75 


38.20 


195 




84,356 


89,883.96 


5,527.96 


42.50 


39.89 


178 


1,335 


83,256 


85,336.14 


2,080.14 


43.90 


42.83 


1.646 


7,326 


666,588 


676,278.29 


9,690.29 


39.80 


39.23 


16 


2,209 


5,951 


6,518.74 


567.74 


35.00 


31.94 


31 


67 


16,446 


16,662.22 


216.22 


46.60 


45.99 


5,691 




2,292,973 


2,327,303.98 


34,330.98 


40.65 


40.05 


31 


111 


17,106 


17,442.11 


336.11 


46.90 


46.00 


290,954 


753,059 


116,882,455 


118,555,784,91 


1,673,329.91 









126 



Appendix II — Financial 



SOUTHERN ONTARIO 



Summary of the Allocation 
for the Year 





Power and energy 

supplied during year 

(principal bases 

of cost allocation) 


Cost of 




Average of 

monthly 
peak loads 


Energy 


Power 

purchased, 

operating 

costs, and 

fixed 

charges 

(Note 2) 


Frequency 
standardi- 
zation 
(Note 3) 


Provision 

for 

stabilization 

of rates and 

contingencies 

(Note 4) 


Provision 

for 

nuclear 

research 

(Note 5) 


Municipalities 

Rural Power District 

Direct customers (Note 1): 
Municipal 

Rural 


kw 
2,968,929.9 
485,653.7 

236,483.0 

362.169.7 
1.173.7 


megawatt- 
hours 
16.828.812.9 
2,508,393.6 

2,094,095.7 

2,538,623.7 
4,972.0 

2,825,767.0 
1,187.010.7 


$ 
102.566.485 
19,058,723 

9,973,832 

13,198.690 
105,176 

321,415 


$ 
11,809,145 
1.413,226 

255,447 

394,486 


$ 
2,968,930 
485,654 

/236.4831 
\394.519J 

362.169 
1.174 


$ 

290,954 
45,517 

31,283 

39,665 
101 


Secondary energy: 


4,420,415 




Other (Note 2) 






















4,054.410.0 


27,987,675.6 


145.224,321 


18,292,719 


4,448,929 


407,520 







NOTES 

1. In 1960, two separate categories of direct customers have been recognized, namely, those 
located within the boundaries of cost-contract municipalities (Municipal Direct Customers) 
and those located outside these boundaries (Rural Direct Customers). The cost of power of 
municipal direct customers has been reduced, and that of municipalities with matured sinking 
funds correspondingly increased, by $88,142, an amount calculated by dividing the total credit 
resulting from these matured sinking funds ($841,201) in proportion to the average monthly peak 
loads of the two groups. Also in 1960, a provision for stabilization of rates and contingencies has 
been made in an amount equal to the net income from municipal direct customers ($394,519 — 
see Note 4), the reserve so created to be retained for the future benefit of these customers as a 
group. The net income from rural direct customers has been deducted from the cost of power 
of the Rural Power District. 

In prior years the cost of power of direct customers was not reduced by amounts calculated 
with reference to the credit resulting from matured sinking funds, and the net income or loss 
from serving these customers was applied to reduce or increase the cost of power of municipalities 
and the Rural Power District proportionally to their average monthly peak loads. 

Except as indicated above, the method used in 1959 to allocate the cost of power supplied to 
each customer was followed in 1960. 

2. The total of $145,224,321 shown under the heading "Power purchased, operating costs, 
and fixed charges" includes the following items of cost shown in the Statement of Operations: 

Cost of power purchased $ 12,586,660 

Operation, maintenance, and administrative expenses 51,101,847 

Interest 60,055,602 

Depreciation 13,074,301 

Sinking fund provision 16,250,362 

Interchange of power with Northern Ontario Properties 

(1,357,163 megawatt-hours) 4,503,699 

Sale of secondary energy, other than 60-cycle export 3,340,752 

$145,224,321 



Southern Ontario System — Cost of Primary Power 



127 



SYSTEM 

of the Cost of Primary Power 
Ended December 31, 1960 



primary power 










Amounts 
billed 
for primary- 
power 
(municipalities 
at interim 
rates) 




Credit 
resulting 

from 
matured 
sinking 

fund 
(Note 1) 


Sale of 
60-cycle 
secondary 
export 
energy 


Total cost 

of primary 

power 


Net 

income 

from 

rural 

direct 

customers 

(Note 1) 


Net cost 

of primary 

power 


Balance 
credited 

or 
charged 


$ 
753,059 


$ 


$ 
116,882,455 
21,003.120 

10.803.422 

13.995.010 
106.451 


$ 


$ 
116,882,455 
20,634,771 

10,803.422 

14,379,358 
90,452 


$ 
118,555,784.91 
20,634,771.00 

10,803,422.00 

14,379,358.00 
90,452.00 


% 
1,673,329.91 






368,349 




88,142 










384,348 
15,999 












4,741,830 






























841,201 


4,741,830 


162,790,458 




162,790,458 


164,463.787.91 


1,673,329.91 









3. Frequency standardization costs are shown in the Statement of Operations as follows: 

Interest $ 7,487,076 

Portion of cost written off 10,805,643 



$ 18,292,719 



This represents a charge to all customers in the Niagara Division (except those which are not being 
supplied at 60 cycles) at the rate of $5 per kilowatt on the average monthly peak load supplied 
amounting to $13,872,304 plus an amount equal to the net revenue on the export of 60-cycle 
secondary energy amounting to $4,420,415. 

4. The provision for stabilization of rates and contingencies totalling $4,448,929 consists of 
a charge of $1 per kilowatt on the average monthly peak load supplied to all customers ($4,054,410) 
plus an amount equal to the net income from municipal direct customers ($394,519 — see Note 1) 
to be retained for the future benefit of these customers as a group. 

5. The provision of $407,520 for nuclear research was charged to all customers within the 
system on the basis of 50 per cent on the quantity of energy supplied and 50 per cent on average 
monthly peak loads. It represents the Southern Ontario System's share of a total provision of 
$500,000 charged proportionally on the basis of average monthly peak loads in the Southern 
Ontario System and the Northern Ontario Properties. 



128 



Appendix II — Financial 



SOUTHERN ONTARIO SYSTEM 

STATEMENT OF SINKING FUND EQUITY 

as at December 31, 1960 



Municipality 



Net amount paid as part of cost of power by each municipality together 

with proportionate share of other sinking funds provided out of revenues 

of the system and interest allowed 





Net provision 


Sinking fund 




Balance at 


and interest 


equity acquired 


Balance at 


January 1, 1960 


credited 


through 


December 31, 1960 




during year 


annexation 




$ 


$ 


$ 


$ 


366,083.60 


29,590.34 




395,673.94 


53,036.50 


3,301.46 




56,337.96 


75,505.44 


25,781.22 




101,286.66 


133,969.51 


13,784.78 




147,754.29 


6,198.72 


1,982.95 




8,181.67 


130,136.76 


13,427.47 




143,564.23 


50,497.07 


8,091.88 




58,588.95 


51,940.19 


3,160.61 




55,100.80 


287,018.81 


24,174.75 




311,193.56 


116,277.59 


13,460.10 




129,737.69 


12,543.87 


891.75 




13,435.62 


29,584.52 


2,633.38 




32,217.90 


195,013.47 


25,241.54 




220,255.01 


77,503.68 


6,217.15 




83,720.83 


32,114.57 


3,009.58 




35,124.15 


163,545.15 


26,588.81 


39.97 


190,173.93 


3,756.73 


786.27 




4,543.00 


263,593.58 


26,227.74 




289,821.32 


68,293.02 


4,820.72 




73,113.74 


114,312.36 


6,376.49 




120,688.85 


28,519.40 


7,245.78 


383.35 


36,148.53 


905,632.76 


93,915.31 




999,548.07 


10,751.82 


2,146.07 




12,897.89 


16,240.50 


1,989.62 




18,230.12 


186,836.85 


15,553.47 




202,390.32 


79,288.11 


9,047.52 




88,335.63 


91,099.00 


4,796.96 




95,895.96 


56,435.36 


4,203.41 




60,638.77 


59,052.73 


5,291.11 




64,343.84 


1,190,115.41 


133,271.62 


878.11 


1,324,265.14 


163,181.97 


12,215.28 




175,397.25 


34,900.13 


3,055.01 




37,955.14 


52,146.98 


4,920.88 




57,067.86 


25,475.87 


4,148.03 


159.39 


29,783.29 


76,965.91 


7,739.66 




84,705.57 


61,001.29 


3,912.05 




64,913.34 


441,786.37 


41,639.45 




483,425.82 


1,860.64 


169.43 




2,030.07 


102,659.73 


11,324.39 




113,984.12 


19,118.36 


6,910.73 




26,029.09 


785,063.33 


69,612.53 




854,675.86 


4,403,552.75 


330,184.11 




4,733,736.86 


202,997.93 


29,971.92 




232,969.85 


24,003.72 


394.85 




23,608.87 


47,010.98 


5,255.44 




52,266.42 



Acton 

Ailsa Craig. . . . 

Ajax 

Alexandria .... 
Alfred 

Alliston 

Almonte 

Alvinston 

Amherstburg. . 
Ancaster Twp. . 

Apple Hill 

Arkona 

Arnprior 

Arthur 

Athens 

Aurora 

Avonmore 

Aylmer 

Ayr 

Baden 

Bancroft 

Barrie 

Barry's Bay. . . 

Bath 

Beachville 

Beamsville .... 

Beaverton 

Beeton 

Belle River 
Belleville 

Blenheim 

Bloomfield. . . . 

Blyth 

Bobcaygeon. . . 
Bolton 

Bothwell 

Bowmanville . . 
Bracebridge. . . 

Bradford 

Braeside 

Brampton 

Brantford 

Brantford Twp 

Brechin 

Bridgeport .... 



Southern Ontario System — Sinking Fund Equity 

SOUTHERN ONTARIO SYSTEM 

STATEMENT OF SINKING FUND EQUITY 

as at December 31, 1960 

(continued) 



129 



Municipality 



Net amount paid as part of cost of power by each municipality together 

with proportionate share of other sinking funds provided out of revenues 

of the system and interest allowed 



Balance at 
January 1, 1960 



Net provision 
and interest 

credited 
during year 



Sinking fund 

equity acquired 

through 

annexation 



Balance at 
December 31, 1960 



Brigden 

Brighton 

Brockville .... 

Brussels 

Burford 

Burgessville . . 
Burk's Falls. . 
Burlington. . . . 
Caledonia. . . . 
Campbellford . 

Campbellville. 
Cannington. . . 

Cardinal 

Carleton Place 
Casselman 

Cayuga 

Chalk River. . 

Chatham 

Chatsworth. . . 
Chesley 

Chesterville . . 
Chippawa. . . . 

Clifford 

Clinton 

Cobden 

Cobourg 

Colborne 

Coldwater 
Collingwood . . 
Comber 

Cookstown. . . 

Cottam 

Courtright . . . 
Creemore .... 
Dashwood 

Deep River. . . 
Delaware. . . . 

Delhi 

Deseronto. . . . 
Dorchester. . . 

Drayton 

Dresden 

Drumbo 

Dublin 

Dundalk 



$ 
41,403.48 
87,744.80 
1,032,719.85 
62,458.29 
67,042.74 

21,881.38 

15,199.84 

582,588.36 

99,425.71 

829.83 

14,082.87 
67,410.40 
58,024.36 
361,353.50 
14,291.99 

44,476.76 

10,335.02 

1,824,184.81 

24,792.22 

151,311.53 

114,826.55 
80,901.16 
35,778.64 

211,780.30 
27,555.26 

475,170.54 
47,147.75 
53,396.45 

588,113.66 
61,409.77 

27,442.98 
23,121.11 
22,351.20 
49,555.65 
35,656.81 

24,642.36 
19,272.36 
107,167.01 
60,388.69 
34,355.27 

49,306.07 

140,079.29 

28,907.97 

22,307.59 

58.507.88 



$ 
2,534.14 
9,284.79 
97,039.79 
5,385.33 
5,810.71 

1,636.26 
3,413.99 
142,204.53 
7,597.03 
2,930.19 

1,228.31 
2,143.42 
6,165.97 
28,271.14 
3,536.68 

3,586.07 
2,263.40 
145,918.39 
2,141.69 
10,904.46 

6,645.06 
8,202.05 
3,051.15 
15,013.21 
3,455.23 

55.324.82 
5,781.91 
3,583.86 

31,110.55 
3,570.39 

2,454.72 
1,961.84 
1,601.05 
2,793.23 
2,688.27 

14,244.69 
1,769.89 

14,164.68 
6,748.55 
2,644.21 

3,453.24 
11,774.17 
2,041.32 
1,791.30 
4.844.32 



9,216.88 



195.00 



$ 
43,937.62 
97,029.59 
1,138,976.52 
67,843.62 
72,853.45 

23,517.64 

18,613.83 

724,792.89 

107,022.74 

3,760.02 

15,311.18 
69,553.82 
64,190.33 
389,624.64 
17,828.67 

48,062.83 

12,598.42 

1,970,103.20 

26,933.91 

162,215.99 

121,471.61 
89,103.21 
38,829.79 

226,988.51 
31,010.49 

530,495.36 
52,929.66 
56,980.31 

619,224.21 
64,980.16 

29,897.70 
25,082.95 
23,952.25 
52,348.88 
38,345.08 

38,887.05 
21,042.25 
121,331.69 
67,137.24 
36,999.48 

52,759.31 
151,853.46 
30,949.29 
24,098.89 
63,352.20 



130 



Appendix II — Financial 

SOUTHERN ONTARIO SYSTEM 

STATEMENT OF SINKING FUND EQUITY 

as at December 31, 1960 

(continued) 



Municipality- 



Net amount paid as part of cost of power by each municipality together 

with proportionate share of other sinking funds provided out of revenues 

of the system and interest allowed 





Net provision 


Sinking fund 




Balance at 


and interest 


equity acquired 


Balance at 


January 1, 1960 


credited 


through 


December 31, 1960 




during year 


annexation 




$ 


$ 


$ 


$ 


608,630.75 


51,735.23 




660,365.98 


322,493.42 


27,746.74 




350,240.16 


133,086.84 


12,013.47 




145,100.31 


71,736.38 


4.616.46 




76,352.84 


2,164,461.54 


224,509.46 




2,388,971.00 


9,355.87 


2,771.23 




12,127.10 


343,881.97 


27,473.28 




371,355.25 


59.806.93 


3,199.28 




63,006.21 


20,572.46 


1,540.90 




22,113.36 


139,196.07 


6,973.84 




146,169.91 


45,541.35 


2,460.65 




48,002.00 


38,481.12 


3,294.24 




41,775.36 


7,015.26 


533.61 




7,548.87 


15,650.42 


3,064.02 




18.714 44 


155,213.44 


11,455.55 




166,668.99 


3,297,425.62 


580,923.02 




3.878,348.64 


205,773.97 


17,632.96 




223,406.93 


320,561.91 


25,927.48 




346,489.39 


23,221.79 


2,097.87 




25,319.66 


28,838.06 


2,683.52 




31.521.58 


57,496.04 


7,082.84 




64,578.88 " 


158,006.78 


12,604.27 




170,611.05 


1,075,373.71 


96,012.95 




1.171,386.66 


20,094.95 


3,591.80 




23,686.75 


2,363,779.35 


173,400.17 




2,537,179.52 


509,983.62 


46,025.34 




556,008.96 


78,098.44 


5,735.94 




83,834.28 


529,410.85 


39,832.43 




569,243.28 


40,588.22 


5,433.53 




46,021.75 


53,825.95 


4,212.04 




58.037.99 


26,241.70 


1,439.67 




27,681.37 


201,441.04 


18,549.64 




219,990.68 


119,699.64 


16,057.99 




135,757.63 


2,822,772.36 


232,010.89 




3.054,783.25 


281,018.68 


16,002.75 




297,021.43 


25,558,236.94 


2,306,898.48 


74.334.06 


27,939,469.48 


357,454.10 


29,486.16 




386,940.26 


147,744.57 


10,975.78 




158,720.35 


134,843.33 


11,070.73 




145,914.06 


28,268.49 


3.024.74 




31,293.23 


52,411.30 


4,392.45 




56,803.75 


47,725.92 


12,862.04 




60,587.96 


75,974.10 


6,244.96 




82,219.06 


558.134.27 


41,332.37 




599,466.64 


34,551.68 


2,188.07 




36,739.75 



Dundas 

Dunnville 

Durham 

Dutton 

East York Twp 

Eganville 

Elmira 

Elmvale 

Elmwood 

Elora 

Embro 

Erieau 

Erie Beach .... 

Erin 

Essex 

Etobicoke Twp. 

Exeter 

Fergus 

Finch 

Flesherton 

Fonthill 

Forest 

Forest Hill 

Frankford 

Gait 

Georgetown. . . 

Glencoe 

Goderich 

Grand Bend . . 
Grand Valley . 

Granton 

Gravenhurst . . . 

Grimsby 

Guelph 

Hagersville 

Hamilton 

Hanover 

Harriston 

Harrow 

Hastings 

Havelock 

Hawkesbury . . 

Hensall 

Hespeler 

Highgate 



Southern Ontario System — Sinking Fund Equity 

SOUTHERN ONTARIO SYSTEM 

STATEMENT OF SINKING FUND EQUITY 

as at December 31, 1960 

(continued) 



131 





Net amount paid as part of cost of power by each municipality together 

with proportionate share of other sinking funds provided out of revenues 

of the system and interest allowed 


Municipality 


Balance at 
January 1, 1960 


Net provision 
and interest 

credited 
during year 


Sinking fund 

equity acquired 

through 

annexation 


Balance at 
December 31. 1960 


Holstein 


$ 

11.133.37 

289,446.73 

723,705.68 

39,007.60 

56,700.41 

114,681.20 

211,214.45 

1,852,957.19 

184,551.98 

12,223.53 

5,796,797.16 
90,403.08 
56,280.10 
29,878.49 
24,217.60 

484,363.40 
623,793.29 
347,183.38 
9,132.823.72 
125.417.99 

331,233.94 

7,542.17 

73,264.84 

89,673.66 

44,449.75 

60,180.70 

2,906.53 

52,488.19 

123,659.85 

42,641.57 

11,208.12 
42,135.05 
192.708.24 
41,413.88 
14,810.25 

1,268,541.61 

851,543.16 

30,541.76 

21,698.57 

417,591.92 

150,088.98 

657,763.72 

187,564.54 

24,763.52 

61.803.12 


$ 

927.33 

23,125.87 

44,782.23 

4,670.30 

3,834.04 

11,650.25 

19,007.58 

225,550.29 

13,514.08 

776.94 

446,718.89 
8,728.12 
5,904.20 
2,524.14 
2,155.70 

43.641.54 
62,046.73 
25,825.34 
572,777.95 
11,648.72 

40.338.36 
1,822.69 
5,195.59 
7,017.95 
2,849.99 

6,259.23 

533.26 

5,082.53 

16,754.39 

4,910.66 

1,093.32 
3,716.40 
19,861.33 
2,898.56 
2,439.41 

128,939.66 

53,171.73 

3,509.67 

2,891.94 

28,459.67 

9,401.56 

58,638.55 

13,647.58 

1,851.54 

7,848.12 


$ 
919.60 


$ 

12.060.70 


Huntsville 


312.572.60 




768,487.91 




43.677.90 




60,534.45 




126,331.45 


Kincardine 


230,222.03 


Kingston 


2,078,507.48 


Kingsville 


198,066.06 


Kirkfield 


13,000.47 


Kitchener 


6,243,516.05 


Lakefield 


99,131.20 


Lambeth 


62.184.30 


Lanark 


32,402.63 


Lancaster 


26.373.30 


Leamington 


528,004.94 


Lindsay 


685.840.02 


Listowel 


373,008.72 


London 


9,706,521.27 


London Twp 


137,066.71 


Long Branch 


371,572.30 


L'Orignal 


9,364.86 




78,460.43 


Lucknow 


96,691.61 




47,299.74 




66.439.93 


Magnetawan 


3.439.79 




57,570.72 


Markham 


140,414.24 




47,552.23 


Martintown 


12,301.44 


Maxville 


45.851.45 




212,569.57 


Merlin 


44,312.44 




17,249.66 


Merritton 


1,397,481.27 


Midland 


904,714.89 


Mildmay. . . . 


34,051.43 


Millbrook . . 


24,590.51 


Milton 


446,051.59 


Milverton .... 


159,490.54 


Mimico 


716,402.27 


Mitchell 


201,212.12 


Moorefield . . . 


26,615.06 


Morrisburg. . . 


69.651.24 



132 



Appendix II — Financial 

SOUTHERN ONTARIO SYSTEM 

STATEMENT OF SINKING FUND EQUITY 

as at December 31, 1960 

(continued) 



Municipality 



Net amount paid as part of cost of power by each municipality together 

with proportionate share of other sinking funds provided out of revenues 

of the system and interest allowed 



Balance at 
January 1, 1960 



Net provision 
and interest 

credited 
during year 



Sinking fund 

equity acquired 

through 

annexation 



Balance at 
December 31. 1960 



Mount Brydges. 
Mount Forest. . 

Napanee 

Neustadt 

Newboro 



Newburgh 

Newbury 

Newcastle 

New Hamburg. 
Newmarket . . . 



New Toronto .... 

Niagara 

Niagara Falls 
North York Twp. 
Norwich 



Norwood 

Oakville-Trafalgar . 

Oil Springs 

Omemee 

Orangeville 



Orillia 

Orono. . . . 
Oshawa. . 
Ottawa. . 
Otterville. 



Owen Sound . 

Paisley 

Palmerston. . 

Paris 

Parkhill 



Parry Sound. . . . 
Penetanguishene . 

Perth 

Peterborough. . . 
Petrolia 



Pickering 

Picton 

Plattsville .... 
Point Edward 
Port Burwell . 



Port Colborne. . 
Port Credit. . . . 
Port Dalhousie. 
Port Dover .... 
Port Elgin 



32,945.65 
159,828.19 
267,397.36 

25,885.01 
3,324.27 

8,396.78 

16,904.93 

41,685.22 

182,878.22 

216,892.38 

2,171,071.51 

161,133.05 

2,141,907.27 

4,260,811.75 

135,163.62 

40,366.95 

609,229.69 

74,471.65 

24,000.56 

233,091.83 

102,033.37 

20,304.31 

3,639,181.23 

4,855,038.98 

38,161.35 

1,124,276.94 

48,292.95 

165,842.25 

438,826.05 

85,057.13 



$ 

2.768.83 

14,572.13 

26,051.89 

2,152.40 

525.97 

1,474.87 

1,201.20 

5,193.41 

11,139.13 

34,715.70 

180,887.86 

13,287.32 

145,671.29 

808,179.47 

7,588.54 

4,260.68 

147,151.19 

4.021.87 

2,793.02 

23,526.67 

25,483.33 

2,874.17 

402,364.25 

804,898.56 

3,089.45 

93,123.08 

3,785.72 

10,694.69 

28,057.04 

7,071.29 



59,290.12 


11.352.60 


251,435.04 


11,923.40 


346,399.63 


30,720.99 


2,399,427.12 


247,384.08 


344,109.15 


20,426.37 


5,078.59 


3,511.14 


299,991.69 


27,558.67 


48,772.15 


3,309.89 


346,357.37 


28.988.29 


17,779.29 


1,712.17 


554,681.41 


46,279.26 


339,363.19 


58,337.53 


178,072.03 


13,616.88 


145,324.14 


14,043.97 


99,453.89 


9.523.16 



1,122.97 



35,714.48 
174,400.32 
293,449.25 

28,037.41 
3,850.24 

9,871.65 

18,106.13 

46,878.63 

194,017.35 

252,731.05 

2,351,959.37 

174,420.37 

2,287,578.56 

5,068,991.22 

142,752.16 

44,627.63 

756,380.88 

78,493.52 

26,793.58 

256,618.50 

127,516.70 

23,178.48 

4,041,545.48 

5,659,937.54 

41,250.80 

1,217,400.02 

52,078.67 

176,536.94 

466,883.09 

92,128.42 

70,642.72 

263,358.44 

377,120.62 

2,646,811.20 

364,535.52 

8,589.73 
327,550.36 

52,082.04 
375,345.66 

19,491.46 

600,960.67 
397,700.72 
191,688.91 
159,368.11 
108.977.05 



Southern Ontario System — Sinking Fund Equity 

SOUTHERN ONTARIO SYSTEM 

STATEMENT OF SINKING FUND EQUITY 

as at December 31, 1960 

(continued) 



133 



Municipality 



Net amount paid as part of cost of power by each municipality together 

with proportionate share of other sinking funds provided out of revenues 

of the system and interest allowed 



Balance at 
January 1, 1960 



Net provision 
and interest 

credited 
during year 



Sinking fund 

equity acquired 

through 

annexation 



Balance at 
December 31, 1960 



Port Hope 


502,748.53 
60,933.54 
94,915.19 
31,875.03 

165,391.31 

266,363.72 

1,001,194.38 

4,407.39 

38,002.49 

30,620.92 

125,786.31 

23,445.67 

233,182.10 

166,936.79 

34,932.64 

429,526.40 
17,354.89 
46,003.73 
56,473.43 
14,933.51 

24,755.91 
3,691,368.81 
35,800.54 
53,872.98 
68.770.00 

519,037.97 

1.825,214.31 

193.005.10 

348,802.09 

3,498,588.38 

3,446,713.16 

214,858.49 

89,030.80 

552,539.45 

546,534.05 

33,341.43 
94,746.43 
31,878.17 
722,698.38 
80,945.99 

57,793.33 
90.698.06 

110,222.33 
2,081,097.41 

364,031.91 


$ 
50,424.94 
6,423.34 
9,435.61 
2,432.00 
9,174.65 

21,696.55 

67,919.78 

366.30 

2,227.10 

2.637.84 

21,396.45 

3,163.83 

48,078.28 

12.516.47 

2,788.31 

42,575.06 
4,568.20 
3,039.15 
4,553.94 
1,048.31 

2,116.24 
314,488.75 
3,774.02 
4,158.92 
4,784.80 

58,301.52 
114,399.57 
32,540.20 
59,435.08 
688,468.54 

643,303.53 

10,810.34 

7,266.23 

51,007.58 

49,391.36 

3,860.66 
8,935.86 
2,141.13 
90,732.94 
5.769.84 

5.692.73 

18,014.92 

12,609.89 

130,889.90 

23,663.28 


$ 
600.33 


$ 
553,173.47 


Port McNicoll 


67,356.88 


Port Perry 


104,350.80 


Port Rowan 


34,307.03 




174,565.96 


Prescott. 


288,060.27 




1,069,114.16 


Priceville 


4,773.69 


Princeton 


40,229.59 




33,258.76 




147,182.76 


Richmond 


26,609.50 


Richmond Hill 


281,260.38 


Ridgetown 


179,453.26 


Ripley 


37,720.95 


Riverside 


472,101.46 


Rockland 


21,923.09 


Rockwood 


49,042.88 


Rodney 


61,027.37 


Rosseau 


15,981.82 


Russell 


26,872.15 


St. Catharines 


4,005,857.56 


St. Clair Beach 


40,174.89 




58,031.90 


St. Jacobs 


73,554.80 


St. Mary's 


577,339.49 




1,939,613.88 


Sandwich East Twp 


225,545.30 


Sandwich West Twp 


408,237.17 


Sarnia 


4,187,056.92 


Scarborough Twp 


4,090,016.69 


Seaforth 


225,668.83 


Shelburne 


96,297.03 




603,547.03 


Smith's Falls 


595,925.41 


Smithville 


37,202.09 




103,682.29 


Springfield 


34.019.30 




813,431.32 


Stayner 


86,715.83 


Stirling 


63,486.06 


Stoney Creek 


108,712.98 


Stouffville 


122,832.22 




2.211.987.31 


Strathroy 


387,695.19 



134 



Appendix II — Financial 

SOUTHERN ONTARIO SYSTEM 

STATEMENT OF SINKING FUND EQUITY 

as at December 31, 1960 

(continued) 



Municipality- 



Net amount paid as part of cost of power by each municipality together 

with proportionate share of other sinking funds provided out of revenues 

of the system and interest allowed 





Net provision 


Sinking fund 




Balance at 


and interest 


equity acquired 


Balance at 


January 1, 1960 


credited 


through 


December 31, 1960 




during year 


annexation 




$ 


$ 


$ 


$ 


90,062.58 


15,567.50 




105,630.08 


41.880.92 


994.24 




42,875.16 


9,066.47 


2,131.66 




11,198.13 


92,165.27 


8,388.61 




100,553.88 


480,911.20 


43,760.45 




524,671.65 


37,277.72 


3,278.11 




40,555.83 


165,033.20 


9,671.33 




174,704.53 


127,988.83 


10,663.55 




138.652.38 


56,737.57 


5,288.50 




62.026.07 


69,651.91 


4,731.07 




74,382.98 


75.749.36 


6,041.97 




81,791.33 


43,852.10 


3,731.08 




47,583.18 


23,102.43 


4,496.10 




27,598.53 


32,610.09 


1,246.40 




33.856.49 


13,359.48 


1.001.38 




14.360.86 


647,077.76 


72,859.11 




719.936.87 


220,433.97 


14,453.36 




234.887.33 


383,280.65 


28,367.23 




411.647.88 


73,548,040.34 


5,120,435.86 




78.668.476.20 


1,551,087.79 


274,486.51 




1,825.574.30 


44,060.61 


3,440.42 




47,501.03 


749,667.43 


92,103.70 




841,771.13 


71,957.66 


7,256.31 




79,213.97 


108,810.79 


11,563.43 




120,374.22 


11.921.55 


2,737.86 




14.659.41 


28,926.52 


1,906.06 




30,832.58 


168,773.73 


17,582.95 




186,356.68 


948,033.88 


68,208.36 




1,016,242.24 


17,715.59 


1,555.62 




19,271.21 


21,244.02 


1,900.76 




23,144.78 


17.206.39 


3,478.26 




20.684.65 


89,880.31 


6,725.21 




96,605.52 


123,581.46 


8,850.26 




132,431.72 


1,229,740.27 


102,096.61 


6.371.12 


1,338,208.00 


111,608.74 


9,813.35 




121,422.09 


25,126.34 


1,911.05 




27,037.39 


1,486,317.18 


108,289.69 




1.594,606.87 


56,190.95 


3,737.64 




59,928.59 


55,452.08 


4,843.08 




60,295.16 


114,754.27 


9,129.17 




123,883.44 


990,575.82 


68,382.03 




1,058,957.85 


29,891.59 


2,745.66 




32,637.25 


74,054.72 


6,642.19 




80,696.91 


400,349.90 


57,808.01 




458,157.91 


95,346.54 


9,712.86 




105,059.40 



Streetsville 

Sunderland 

Sundridge 

Sutton 

Swansea 

Tara 

Tavistock 

Tecumseh 

Teeswater 

Thamesford 

Thamesville 

Thedford 

Thornbury 

Thorndale 

Thornton 

Thorold 

Tilbury 

Tillsonburg 

Toronto 

Toronto Twp. . . . 

Tottenham 

Trenton 

Tweed 

Uxbridge 

Vankleek Hill. .. 

Victoria Harbour 

Walkerton 

Wallaceburg. . . . 

Wardsville 

Warkworth 

Wasaga Beach. . 

Waterdown 

Waterford 

Waterloo 

Watford 

Waubaushene . . 

Welland 

Wellesley 

Wellington 

West Lome 

Weston 

Westport 

Wheatley 

Whitby 

Wiarton 



Southern Ontario System — Sinking Fund Equity 

SOUTHERN ONTARIO SYSTEM 

STATEMENT OF SINKING FUND EQUITY 

as at December 31, 1960 

(concluded) 



135 





Net amount paid as part of cost of power by each municipality together 

with proportionate share of other sinking funds provided out of revenues 

of the system and interest allowed 


Municipality 


Balance at 
January 1, 1960 


Net provision 
and interest 

credited 
during year 


Sinking fund 

equity acquired 

through 

annexation 


Balance at 
December 31, 1960 




$ 

25,943.17 

98,369.58 

13,298.49 

11,789,088.96 

193,158.65 

180,538.38 

1,743,836.06 

34.478.27 

37.681.53 

4,202,471.47 

51,498.72 


$ 

1.946.73 

7.319.78 

1.078.94 

711.094.56 

17,613.35 

14,497.54 

132,232.44 

121.87 

3,142.26 

410,437.86 

3,741.94 


$ 


$ 

27.889.90 




105.689.36 




14,377.43 




12,500,183.52 




210,772.00 




195,035.92 




1.876,068.50 ! 


Woodville 


34,356.40 




40,823.79 




4,612,909.33 




55,240.66 






Total — Municipalities 


238,662.672.26 
41,209.595.84 

3,610,148.31 


21,377.764.14 
6.528,912.83 

335.272.61 


94,220.78 
94,220.78 


260,134,657.18 
47,644,287.89 


Administrative and service buildings 


3,945,420.92 






Grand Total 


283,482,416.41 


28,241,949.58 
(see note) 




311,724,365.99 



Note: The net provision and interest credited during the year consist of the following amounts shown 
in the Statement of Sinking Fund Reserve. 

Interest $11,339,296.90 

Provision— direct 17,548,125.00 

—indirect 248,071.00 

$29,135,492.90 
Less credits resulting from matured sinking funds 893,543.32 

$28,241,949.58 



136 



Appendix II — Financial 



NORTHERN ONTARIO 

FIXED 

Statement Showing Changes during 





'In 




Balance 

January 1, 

1960 


Changes 


Property 


Placed 

in 
service 


Equipment 
relocated 

and 
reclassified 


Power System 

Hydro-electric Generating Stations 
northeastern division 
Abitibi River 

Abitibi Canyon . . . 


$ 
20,979,499 


$ 

45,440 
484 


$ 


Otter Rapids 


137,747 


Mattagami River 

Little Long 






Mississagi River 

George W. Rayner 


18,532,785 


3,025 
8,640,000 
1,668,119 




Red Rock Falls 


8,568 


Other properties 


23,639,329 


141,462 








63,151,613 


10,357,068 


4,853 


NORTHWESTERN DIVISION 

Nipigon River 

Pine Portage 


31,970,202 
15,453,562 
11,428,791 

12,678,175 

23,814,619 
15,348,702 

20,762,835 

16,162,462 
11,282,979 


1,733 
121,252 
241,793 

4,912 

65,790 
153,313 

291,787 

108,374 
132,235 


4,693 


Cameron Falls 


4,664 


Alexander 


204,954 


Aguasabon River 

Aguasabon 




English River 

Caribou Falls 


182,235 


Manitou Falls 




Winnipeg River 

Whitedog Falls 


182,235 


Kaministikwia River 
Silver Falls 




Other properties 


42,011 








158,902,327 


1,117,723 


153,586 


Thermal-electric Generating 

Stations 
northeastern division. . , 


387,490 


412 




NORTHWESTERN DIVISION 

Thunder Bay 














387,490 


412 








Total generating stations 


222,441,430 


11,474,379 


158,439 


Transformer Stations 
Northeastern Division. . . . 


24,660,132 
10,182,984 


1,124,693 
677,656 


10,901 


Northwestern Division 


179,516 






Total transformer stations 


34,843,116 


1,802,349 


190,417 


Transmission Lines 
Northeastern Division .... 


33,467,890 
30,840,532 


770,251 
254,889 


214 


Northwestern Division. . . . 


6,572 






Total transmission lines 


64,308,422 


1,025,140 


6,358 







Northern Ontario Properties — Fixed Assets 



137 



PROPERTIES 

ASSETS 

Year 1960 and Balances at December 31, 1960 



service 


Under 

construction 

December 31, 

1960 


Total 

fixed assets 

December 31, 

1960 




during year 


Balance 

December 31, 

1960 




Sales 

and 

retirements 


Expenditures 

during 

1960 


$ 
556 


$ 

21,024,383 
138,231 


$ 

150,331 
20,471,644 

5,832,716 

41,147 

7,759,389 

500,587 


$ 

21,174,714 
20,609,875 

5,832,716 

18,576,957 
16,407,957 
25,639,910 


$ 

158,643 
10,493,634 




5,832,716 




18,535,810 

8,648,568 

25,139,323 


38,754 




5,706,029 


26,663 


708,270 


27,219 


73,486,315 


34,755,814 


108,242,129 


22,938,046 


140 

87,355 
5,872 

1,128 


31,963,636 
15,482,795 
11,869,666 

12,681,959 

23,698,174 
15,502,015 

21,236,857 

16,270,836 
11,365,946 


4,965 
27,377 
26,027 

1,435 

157,333 


31,968,601 
15,510,172 
11,895,693 

12,683,394 

23,855,507 
15,502,015 

21,394,167 

16,285,971 
11,429,518 


595 

40,405 

174,486 

2,509 

111,378 




11,776 




157,310 

15,135 
63,572 


337,352 




35,752 


7,257 


16,090 


101,752 


160,071,884 


453,154 


160,525,038 


625,981 




387,078 


4,529 
17,781,333 


391,607 
17,781,333 


4,117 




7,448,868 










387,078 


17,785,862 


18,172,940 


7,452,985 






128,971 


233,945,277 


52,994,830 


286,940,107 


31,017,012 


453,955 
180,554 


25,319,969 
10,500,570 


234,909 
146,878 


25,554,878 
10,647,448 


972,822 
660,038 


634,509 


35,820,539 


381,787 


36,202,326 


1,632,860 


266,348 
84,401 


33,972,007 
31,173,250 


1,307,062 
426,856 


35,279,069 
31,600,106 


1,244,957 
328,290 


181,947 


65,145,257 


l,733 r 918 


66,879,175 


1,573,247 



138 



Appendix II — Financial 



NORTHERN ONTARIO 

FIXED 
Statement Showing Changes during 





In 




Balance 

January 1, 

1960 


Changes 


Property 


Placed 

in 
service 


Equipment 
relocated 

and 
reclassified 


Power System — (Continued) 

Local Systems 

Northeastern Division 


$ 

3,814,070 
611,010 


$ 

334,763 
48,380 


$ 
24,274 


Northwestern Division 


7,195 






Total local systems 


4,425,080 


383,143 


31,469 






Communications 


3,980,059 


157,953 


567 






Total power system 


329,998,107 


14,842,964 


7,434 






Administrative and Service 
Buildings and Equipment 

Buildings 


2,199,185 
761,359 


267,681 
66,674 


42,011 


Office and Service Equipment. . . 








Total administrative and service 
buildings and equipment 


2,960,544 


334,355 


42,011 


Rural Power District 


38,824,379 


2,692,897 


34,577 


Total Fixed Assets . . . 


371,783,030 


17,870,216 









Changes in Assets under Construction during 1960 

1960 



Under construction at January 
Expenditures during 1960 



$ 35,963,514 
37,505,352 



$ 73,468,866 
Less — Placed in service during 1960 17,870,216 



Under construction at December 31, 1960 $ 55,598,650 



Northern Ontario Properties — Fixed Assets 



139 



\ 



PROPERTIES 

ASSETS 

Year 1960 and Balances at December 31, 1960 



service 


Under 

construction 

December 31, 

1960 


Total 

fixed assets 

December 31, 

1960 




during year 


Balance 

December 31, 

1960 




Sales 

and 

retirements 


Expenditures 

during 

1960 


$ 

50,025 
5,803 


$ 

4,123,082 
660,782 


$ 

106,184 
18,760 


$ 

4,229,266 
679,542 


$ 

363,283 
60,885 


55,828 


4,783,864 


124,944 


4,908,808 


424,168 


219,222 


3,918,223 


89,890 


4,008,113 


70,992 


1,220,477 


343,613,160 


55,325,369 


398,938,529 


34,718,279 


8,258 
41,631 


2,500,619 
786,402 


65,252 


2,565,871 
786,402 


130,826 
66,674 








49,889 


3,287,021 


65,252 


3,352,273 


197,500 


1,513,574 


39,969,125 


208,029 


40,177,154 


2,589,573 


2,783,940 


386,869,306 


55,598,650 


442,467,956 


37,505,352 



Summary of Sales and Retirements during 1960 

Charged to operations $ 6,161 

Charged to accumulated depreciation 1,492,853 

Proceeds from sales 1 ,284,926 

$ 2,783,940 



140 



Appendix II — Financial 

NORTHERN ONTARIO 
Accumulated Depreciation, December 31, 1960 





Power 
System 


Rural Power 
District 


Administrative 

and service 

buildings and 

equipment 


Total 


Balances at January 1, 1960. . 
Add: 

Interest at 3% per annum on 
accumulated depreciation 
on plant not fully depre- 
ciated 

Provision in the year 

- — direct. 


$ 
38,224,194 

1,042,876 

2,909,229 

327 

5,474 
111,004 


$ 
7,153,217 

211,552 
1,102,050 


$ 
633,901 

9,100 


$ 
46,011,312 

1,263,528 

4,011,279 
102,765 


— indirect 


102,438 

10,054 
2,544 


Adjustments re transfer of 
equipment 


4,580 
621 




Other adjustments 


114,169 








42,282,156 


8,462,860 


758,037 


51,503,053 


Deduct: 

Cost of fixed assets retired 
less proceeds from sales. . 
Excess or deficiency of re- 
moval costs over salvage 
recoveries on assets retired 


1,076,612 
99,124 


390,497 
25,501 


25,744 


1,492,853 
73,623 










1,175,736 


364,996 


25,744 


1,566,476 


Balances at December 31, 1960 


41,106,420 


8,097,864 


732,293 


49,936,577 



Frequency Standardization Account, December 31, 1960 



Balance at debit at January 1 , 1960 $ 3,583,659 

Expenditures for frequency standardization work completed during year 2,242 

$ 3,585,901 
Less portion of cost charged to cost of power for the year 140,038 

Balance at debit at December 31, 1960 $ 3,445,863 



Exchange Discount (Net) on Funded Debt, December 31, 1960 





Discount 


Premium 


Net discount 


Exchange discount and premium on funded 
debt issued in United States funds: 
Balances at December 31, 1960 — No changes 
during year 


$ 711,656 


$ 176,489 


$ 535,167 







Northern Ontario Properties — Statements of Reserves 
PROPERTIES 

Reserve for Stabilization of Rates and Contingencies, December 31, 1960 



141 





Power 
System 


Rural 

Power 

District 


Sub-total 


Portion of reserve 

earmarked for 

special purposes 






Cost- 
contract 
munici- 
palities in 
the former 
Thunder 

Bay 
System 


Nuclear 
research 


Total 


Balances at January 1, 1960. 
Add: 

Interest for year on reserve 
balances 

Provision in the vear 


$ 
16,420,369 

637,837 


$ 
320,666 

12,483 


$ 
16,741,035 

650,320 


$ 

2,111,558 
82,199 


$ 
76,966 

2,855 
92,480 


$ 
18,929,559 

735,374 
92,480 


Profit on sale of invest- 
ments, net 


45,808 




45,808 




45,808 












17,104,014 


333,149 


17,437,163 


2,193,757 


172,301 


19,803,221 


Deduct: 

Expenditures during year. . 










14,149 


14,149 


Withdrawal in the year 
applied in reduction of 
cost of power 








465,170 


465,170 














465,170 


14,149 


479,319 


Balances at December 31, 
1960 


17,104,014 


333,149 


17,437,163 


1,728,587 


158,152 


19,323,902 



Sinking Fund Reserve, December 31, 1960 





Province of Ontario 


Municipali- 
ties supplied 
with power 
at cost 






40-year 
basis 


Prepaid 
sinking 
funds 


Total 


40-year 
basis 


Total 


Balances at January 1, 1960. . . 
Add: 

Interest at 4% per annum on 

reserve balances 

Provision in the year 
— direct 


$ 
37,230,894 

1,489,237 

3,204,151 
26,535 


$ 
12,926,197 

517,046 


$ 
50,157,091 

2,006,283 

3,204,151 
26,535 


$ 
13,275,645 

531,027 
524,087 


$ 
63,432,736 

2,537,310 

3,728,238 


— indirect. . 




26,535 












41,950,817 


13,443,243 


55,394,060 


14,330,759 


69,724,819 


Deduct credits resulting from 
prepaid and matured sink- 
ing funds (see note): 
Interest 


17,318 
4,559 


517,048 
185,158 


534,366 
189,717 




534,366 


Principal 




189,717 










21,877 


702,206 


724,083 




724,083 








Balances at December 31, 1960 


41,928,940 


12,741,037 


54,669,977 


14,330,759 


69,000,736 



Note: The matured sinking funds at January 1, 1960 amounted to $432 



142 



Appendix II — Financial 



NORTHERN ONTARIO 

STATEMENT OF THE ALLOCATION 

for the Year 



Municipalities supplied 
with power at cost 



Power and energy 

supplied during year 

(principal bases 

of cost allocation) 



Average of 

monthly 
peak loads 



Energy 



Cost of 



Power 




purchased. 


Provision 


operating 


for 


costs, and 


nuclear 


fixed charges 


research 


(Note 1) 


(Note 3) 



Atikokan Twp 

Cache Bay 

Capreol 

Cochrane 

Coniston 

Dryden 

Espanola 

Fort William 

Kapuskasing 

Larder Lake Twp 

Latchford 

Massey 

McGarry 

Nipigon Twp 

North Bay 

Port Arthur 

Red Rock 

Schreiber Twp 

Sturgeon Falls 

Sudbury 

Terrace Bay 

Thessalon 

Webbwood , 

West Ferris Twp 

Total — Municipalities 



kw 

3,998.5 

532.2 

1,675.7 

2,542.2 
185.3 

2,334.0 

645.3 

32,896.1 

3,660.9 

841.1 

170.7 

125.8 

906.6 

1,451.2 

14,097.3 

39,956.2 

803.2 

1,148.6 

2,307.5 

13,053.9 

1,273.1 

634.2 

42.2 

667.9 



megawatt- 
hours 
23,141.5 
1,474.5 
8,588.7 
13,396.8 
979.9 

14,369.0 

3,091.2 

211,144.0 

17.142.2 
4,320.6 

730.8 

651.0 

4,393.2 

8,010.1 

78,166.1 

208,227.1 
4,056.0 
6,414.2 
11,546.1 
70,645.2 

8,009.6 

3,524.0 

186.3 

3,390.0 



$ 
183,548 
18,736 
66,264 
82,242 
6,667 

109,018 

22,402 

1,306.142 

125,641 
35,736 

6,676 

5,601 

34,685 

58,962 

512,017 

1,490,412 

30,378 

44,301 

87,064 

490,996 

50,231 

26,753 

1,642 

24,287 



388 

38 

150 

232 

17 

233 

56 

3,361 

317 

75 

15 

11 

80 

138 

1,313 

3,693 

73 

110 

205 

1,203 

129 

59 

3 

60 



125.949.7 



705,598.1 



4,820,401 



11,959 



Northern Ontario Properties — Cost of Primary Power 



143 



PROPERTIES 

OF THE COST OF PRIMARY POWER 
Ended December 31, 1960 



primary power 


Amounts 

billed for 

primary power 

(municipalities 

at interim 

rates) 


Balance 
credited 

or 
charged 


Annual rates on 
a kilowatt basis 


Withdrawal 
from 

stabilization 
of rates 
reserve 
(Note 4) 


Total cost 

of primary 

power 


Interim 


Actual 


$ 


$ 

183.936 

18,774 

66,414 

82,474 

6,684 

109.251 

22.458 

1.112,127 

125.958 
35,811 

6,691 

5.612 

34.765 

50,393 

513,330 

1,254.368 

25,632 

37,519 

87,269 

492,199 

42,721 

26,812 

1,645 

24,347 


188,905.55 

21,287.67 

72.892.97 

94,062.65 

7,336.23 

112,980.77 

25,811.00 

1.102.018.79 

131,793.90 
37,009.51 

7,337.97 

6.069.45 

38,982.73 

50.065.85 

542,744.46 

1,258,620.85 

25,783.54 

37,903.55 

94,607.50 

502,576.75 

42,011.49 

29,489.94 

1,806.84 

27.150.81 


$ 

4,969.55 

2,513.67 

6,478.97 

11,588.65 

652.23 

3,729.77 
3,353.00 
10,108.21 
5,835.90 
1,198.51 

646.97 

457.45 

4,217.73 

327.15 

29,414.46 

4,252.85 

151.54 

384.55 

7,338.50 

10,377.75 

709.51 
2,677.94 

161.84 
2,803.81 


$ 
47.24 
40.00 
43.50 
37.00 
39.60 

48.41 
40.00 
33.50 
36.00 
44.00 

43.00 
48.25 
43.00 
34.50 
38.50 

31.50 
32.10 
33.00 
41.00 
38.50 

33.00 
46.50 
42.85 
40.65 


$ 

46.00 
35.28 
39.63 
32.44 
36.07 

46.81 
34.80 
33.81 
34.41 

42.58 

39.20 
44.61 
38.35 
34.73 
36.41 

31.39 
31.91 
32.66 

37.82 
37.71 

33.56 
42.28 
38.98 
36.45 




























197,376 




















8,707 




239,737 
4,819 
6,892 








7,639 
















465,170 


4,367,190 


4,459,250.77 


92,060.77 







144 



Appendix II — Financial 



NORTHERN ONTARIO 

Summary of the Allocation 
for the Year 





Power and energy 

supplied during year 

(principal bases 

of cost allocation) 


Cost of 




Average of 

monthly 
peak loads 


Energy 


Power 

purchased, 

operating 

costs, and 

fixed charges 

(Note 1) 


Frequency 
standardi- 
zation 

(Note 2) 


Municipalities 


kw 
125,949.7 


megawatt- 
hours 
705,598.1 


$ 
4,820,401 


$ 


Province of Ontario: 

Rural Power District 


64,003.4 
730,123.8 


342,317.8 

4,810,217.8 

709,038.3 


6,880,762 
29,455,790 


24,973 
291,915 














Total — Province of Ontario 


794,127.2 


5,861,573.9 


36,336,552 


316,888 




920,076.9 


6,567,172.0 


41,156,953 


316,888 







NOTES 

1. The total of $41,156,953 shown under the heading "Power purchased, operating costs, 
and fixed charges" includes the following items of cost shown in the Statement of Operations: 

Cost of power purchased $ 480,206 

Operation, maintenance, and administrative expenses 15,542,162 

Interest 14,000,013 

Depreciation 4,011,279 

Sinking fund provision 3,728,238 

Interchange of power with Southern Ontario System 

(1,357,163 megawatt-hours) 4,503,699 

Sale of secondary energy J, 108,644 

$ 41,156,953 



The method used in 1959 of allocating the cost of power supplied to each customer was followed 
in 1960 except that high-voltage transmission costs in the Northwestern Division (other than 
those associated with certain radial lines serving specific customers) were allocated on a demand 
basis to all customers in the Division, whereas in 1959 approximately 40 per cent of these costs 
were so allocated, the remainder being segregated by district and allocated on a demand basis to 
customers within each district. 



Northern Ontario Properties — Cost of Primary Power 



145 



PROPERTIES 

of the Cost of Primary Power 

Ended December 31, 1960 



primary power 


Amounts 

billed for 

primary power 

(municipalities 

at interim 

rates) 




Provision 

for 

nuclear 

research 

(Note 3) 


Credit 

resulting 

from 

prepaid and 

matured 
sinking funds 


Withdrawal 

from 

stabilization 

of rates 

reserve 

(Note 4) 


Total cost 

of primary 

power 


Balance 
credited 

or 
charged 


11,959 


$ 


465,170 


$ 
4,367,190 

6.911,630 
29,098,248 


$ 
4,459,250.77 

6,483,615.04 
29,161,256.11 


$ 
92,060.77 


5,895 




428,014.96 


74,626 


724,083 




63,008.11 




















80,521 


724,083 




36,009,878 


35.644,871.15 


365,006.85 








92,480 


724,083 


465,170 


40,377,068 


40,104,121.92 


272,946.08 



2. Frequency standardization costs are shown in the Statement of Operations as follows: 

Interest $ 176,850 

Portion of cost written off 140,038 



$ 316,888 



This represents a charge of 40 cents per kilowatt on the average monthly peak load supplied to al 
customers served on behalf of the Province of Ontario. 



3. The provision of $92,480 for nuclear research was charged to all customers in the Northern 
Ontario Properties on the basis of 50 per cent on the quantity of energy supplied and 50 per cent 
on average monthly peak loads. It represents the Northern Ontario Properties' share of a total 
provision of $500,000 charged proportionally on the basis of the average monthly peak loads in 
the Southern Ontario System and the Northern Ontario Properties. 

4. The withdrawal of $465,170 from the stabilization of rates reserve is equivalent to $6 per 
kilowatt on the average monthly peak load of cost-contract municipalities formerly served by 
the Thunder Bay System. This amount was charged to that portion of the reserve held specifically 
for those municipalities. 



146 



Appendix II — Financial 
NORTHERN ONTARIO PROPERTIES 



STATEMENT OF SINKING FUND EQUITY 
as at December 31, 1960 





Net amount paid as part of cost of power by 

each municipality, and other sinking funds 

provided out of revenues of the system and 

interest allowed 


Municipality 


Balance at 
January 1, 1960 


Net provision 
and interest 

credited 
during year 


Balance at 
December 31, 1960 


Atikokan Twp. . . 


$ 

58,529.62 

652.35 

1,553.64 

1,933.95 


$ 

24,736.18 

1,373.09 

4,796.15 

5,529.36 

458.00 

15,760.06 

1,544.00 

350,470.84 

8,745.24 

2,629.13 

477.50 

412.00 

2,493.94 

10,968.63 

35,680.42 

523,479.87 

4,906.79 

7,252.84 

6,196.53 

34,228.00 

9,200.17 

1,964.09 

116.00 

1,694.00 


$ 
83,265.80 


Cache Bay 


2,025.44 


Capreol 


6,349.79 


Cochrane 


7,463.31 


Coniston 


458.00 


Dryden 

Espanola 

Fort William 


60,776.50 


76,536.56 
1,544.00 


4,550,221.06 

3,556.04 

878.33 

112.52 


4,900,691.90 


Kapuskasing 


12,301.28 


Larder Lake Twp 

Latchford 


3,507.46 
590.02 


Massey 


412.00 


McGarry 


848.50 
90,015.82 
14,385.41 

8,345,046.81 

33,569.63 

41,821.07 

2,338.16 


3,342.44 


Nipigon Twp. 


100,984.45 


North Bay 


50,065.83 


Port Arthur 


8,868,526.68 


Red Rock 


38,476.42 


Schreiber Twp 


49,073.91 


Sturgeon Falls 


8,534.69 


Sudbury 


34,228.00 


Terrace Bay 


68,704.16 
702.30 


77,904.33 


Thessalon 


2,666.39 


Webbwood 


116.00 


West Ferris Twp. . . 




1,694.00 








Total — Municipalities.. . 
Province of Ontario 


13,275,645.87 
50,157,090.39 


1,055,112.83 
4,512,886.96 


14,330,758.70 
54,669,977.35 


Grand Total 


63,432,736.26 


5,567,999.79 

(see note) 


69,000,736.05 







Note: The net provision and interest credited during the year consist of the following 
amounts shown in the Statement of the Sinking Fund Reserve: 

Interest $ 2,537,309.45 

Provision— direct 3,728,238.00 

—indirect 26,535.00 



$ 6,292,082.45 
Less credits resulting from prepaid and matured sinking funds. . . 724,082.66 

$ 5,567,999.79 



APPENDIX HI— RURAL 



POWER is delivered in wholesale quantities by the Commission to 100 rural 
operating areas in the Rural Power District. Within the areas, retail customers 
are supplied under the following six classes of service: farm, hamlet residential, 
rural residential, commercial, summer, and industrial power. The description 
of these classes of service and the rates applicable to them at December 31, 1960 
are included in this appendix. 

Description of Main Classes of Service 

Farm service means service rendered to a property used for the production 
of food or industrial crops. It provides for the electrical supply of all farm 
buildings and equipment located on a farm and used for farm purposes, including 
equipment required for processing the products of that farm. Service may be 
supplied under one farm contract to all dwellings or separate domestic establish- 
ments located on the farm and occupied by persons engaged in its operation. 
Additional dwellings or domestic establishments located on a farm property 
and occupied by persons otherwise engaged are classed as residential service. 

147 



148 Appendix III — Rural 

Small properties of thirty acres and less are classified as residential service unless 
special circumstances warrant a classification as farm service. 

Hamlet residential service is supplied to all domestic establishments in 
built-up areas where there are six or more customers in any quarter-mile section 
of road or street. 

Rural residential service is supplied to isolated domestic establishments 
served as part of a rural operating area. 

Commercial service applies to a wide variety of business or community 
establishments such as hotels, offices, stores, churches, schools, or small manu- 
facturing and processing plants. Sign and display lighting is included. 

Summer service is applicable to residential properties normally used only 
during the summer months. 

Industrial power service is 3-phase service to such power users as creameries, 
cheese factories, chopping mills, and other industrial establishments. 

Rural Rate Structure 

Rural rates in effect throughout the Province are given in the accompanying 
tables. They are quoted on a monthly basis, except for summer service, which 
is quoted on an annual basis. Each contract within each class of service has a 
rating, and the energy used is billed on the basis of a three-step energy rate, 
except hamlet residential service which has a four-step energy rate, the bill 
being subject to a monthly minimum, or with respect to summer service, to an 
annual fixed charge. The number of kilowatt-hours billed at the first and second 
energy rates and the amount of the minimum monthly bill, or the annual fixed 
charge, depend on the contract rating. For all contracts with a demand rating 
(FD, CD, and Industrial Power) these aspects of the bill are based on measured 
demand and are subject to minima related to demands established in previous 
billing periods. 

For industrial power service there are eight different schedules. These are 
numbered in the following table. The alphabetical list of the 100 rural operating 
areas on page 150 indicates the schedule number of the power service rate 
applicable to each area, as at December 31, 1960. 







,*'*« 



$&*"_/ NORTHEASTERN 
REGION" 



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GEORGIAN BAY 
REGION 



OWEN soun: 



WALKERTON 



SIMCOe ) g»y*jfENE_LOH/ALL^ LAKE " F J ELD 
— £/>V f ».-«..4, 







3- U ?3" 2 t / 


\LLISTON 


/ CLINTON 

L. / MITCHFH 1 


LISTOWEL JL 

/ ELMIRA 




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K\y\ &V*J <#T^ U*o* 



BROCKVILUE. 



FRANKFORC 



> EASTERN REGION 



CENTRAL REGION 



fOIL SPRINGS 7* 521 l '21 r»w-l bEACHVILLe! I DUND *S 

S 1 T 36*I H K09 Y I 3S f"Si( ,8 "-" = ' § BRENTFORD k.'" 6 ~ " 3 ^" f £ 



'STONEY CREEK 

BEAMSVILLE, 



^ -EAST CENTRAL REGION 



/ 



THE HYDRO-ELECTRIC POWER COMMISSION 
OF ONTARIO 



PROVINCE OF ONTARIO 

SHOWING 

RURAL OPERATING AREAS 



I^-^t// WESTERN REGION 



IWEST CENTRAL^" 
REGION 



Miles oiLin 

Rural Operating Are 

Farm Cuttomei 

Non-Farm Customei 



December 31, I960 



Rates for Rural Electrical Service 



149 



Rural Power District 
RATES AND TYPICAL BILLS FOR ELECTRICAL SERVICE 



as at December 31, 1960 

Rates are quoted on a monthly basis for all services except summer service, which are 
quoted on an annual basis. All are subject to 10% prompt payment discount. 



Class and rating 



Number of kilowatt-hours per month 
billed at uniform kwh rate shown 



4.5* 



2.6* 



1.1* 



1.5* 



B c ^ 
2 § 8 
E c o 

C"* u ha 

s G 



Net monthly bill for 



100 kwh 300 kwh 500 kwh 



Farm 

F35 

F50 

FD 

Hamlet 
Residential 

H20 (see note) 
H35 



Rural 
Residential 

R20 (see note) 
R35 

Commercial 

C20 (see note) 

C35 

C50 

CD 



Summer (on 

annual basis) 
S 



60 
00 



60 

90 

150 

15< 



225§ 



180 
300 
30* 



80 
180 



80 
180 



120 



300 
30* 



675§ 



500 
500 



All additional 



All additional 



All additional 



All additional 



All additional 



$ 

2.25 
3.75 
0.40* 



1.67 
2.25 



1.67 

2.25 



1.50 
2.25 
3.75 
0.40* 



44.44 J § 



$ 

3.37 

4.05 



3.37 
3.37 



3.37 
3.37 



3.37 
3.88 
4.05 



$ 

7.45 
8.73 

8.73f 



5.89 
7.24 



6.46 

7.45 



6.86 
8.26 
9.58 
9.58f 



$ 

10.15 
12.42 
12.42f 



7.87 
9.22 



9.16 
10.15 



9.56 
10.96 
13.77 
13.77t 



Net annual bill for 



500 kwh 


750 kwh 


1,000 kwh 


$ 


$ 


$ 


40.00 


41.40 


46.26 



§Per year 

^Includes annual fixed charge of $22.22 



*Per kw of demand 

■(•Calculated on basis of minimum demand of 10 kw 



Note — The H20. R20, and C20 rates were discontinued as of January 1, 1959 except for existing 2-wire services 
at that date. 

Industrial Power 





e 


e 












Schedule 


J3 


f J 


d 
i* 




* 8 


j* & 


•o 




*3 3 








£ <e 


v.i 


qS 








$ 


1 


50* 
50* 
50* 
50* 
50* 
50* 
50* 
50* 


50* 
50* 
50* 
50* 
50* 
50* 
50* 
50* 


1.35 
1.35 
1.35 
1.35 
1.35 
1.35 
1.35 
1.35 


2 


3 


4 


5 


6 


7 


8 





Energy rate 
per kwh for 



?! 



Net monthly bill for 
use of 1 kw of demand 



100 
hours 



200 
hours 



300 
hours 



i 

2.3 
2.6 
2.8 
3.1 
3.4 
3.7 
4.0 
4.6 



* 

1.5 

1.7 

1.8 

2.0 

2.2 

2.4 

2.6 

3.0 



* 
0.33 
0.33 
0.33 
0.33 
0.33 
0.33 
0.33 
0.33 



$ 
2.92 
3.15 
3.28 
3.51 
3.73 
3.96 
4.18 
4.63 



$ 

3.22 
3.45 
3.58 
3.81 
4.03 
4.26 
4.48 
4.93 



$ 

3.52 
3.74 
3.88 
4.10 
4.33 
4.55 
4.78 
5.23 



Per kw of demand 



150 



Appendix III — Rural 

Rural Operating Areas 

and 

Industrial Power Service Schedules in Effect 



Rural operating 
area 



Schedule 



Rural operating 
area 



Schedule 



Rural operating 
area 



Schedule 



Algoma 

Alliston 

Arnprior . . . . 
Atikokan . . . . 
Aylmer 

Bala 

Bancroft . . . . 

Barrie 

Beachville. . . 
Beamsville. . 

Belleville. . . 
Blenheim 
Bowmanville 
Bracebridge . 
Brampton . . . 

Brantford . . . 
Brockville. . . 
Cannington. . 

Cayuga 

Chatham. . . . 

Clinton 

Cobden 

Cobourg . . . . 

Delta 

Dorchester . . 

Dryden 

Dundas 

Dunnville. . . 

Elmira 

Essex 

Exeter 

Fenelon Falls 

Forest 

Fort Frances. 
Frankford . . . 



Geraldton 

Guelph 

Huntsville 

Kapuskasing. . . 
Kenora 

Kingston 

Kirkland Lake . . 

Kitchener 

Lakefield 

Lancaster 

Listowel 

London 

Lucan 

Manitoulin 

Markdale 

Markham 

Matheson 

Merlin 

Merrickville 
Minden 

Mitchell 

Napanee 

New Liskeard . . . 

North Bay 

Norwood 

Oil Springs 

Orangeville 

Orillia 

Oshawa 

Ottawa 

Owen Sound. . . . 
Parry Sound. . . . 
Penetanguishene 

Perth 

Peterborough . . . 



Picton 

Plantagenet 

Port Arthur 

Richmond Hill. . . . 
Ridgetown 

St. Catharines .... 

St. Thomas 

Sarnia 

Shelburne 

Simcoe 

Stayner 

Stoney Creek 

Caledonia Section 

Stratford 

Strathroy 

Sudbury 

Sutton 

Terrace Bay 

Tillsonburg 

Timmins 

Tweed 

Uxbridge 

Vankleek Hill 

Walkerton 

Wallaceburg 

Warren 

Welland 

West Lome 

Winchester 

Wingham 

Woodbridge 



Miles of Line and Number of Customers 



151 



Rural Power District 

MILES OF LINE, NUMBER OF CUSTOMERS 

as at December 31, 1960 





Miles of 

primary 

line 


Number of customers 


Rural operating 
areas by regions 


Farm 


Residential 


Com- 
mercial 


Summer 


Power 




Rural 


Hamlet 


Com- 
mercial 


Other 


Total 


Southern 
Ontario System 

western 

Aylmer 

Beachville 

Blenheim 

Chatham 


336.68 
498.86 
141.72 
311.61 

258.75 

924.81 
274.66 
339.71 
416.39 
379.27 

395.29 
362.74 
370.91 
316.71 
288.30 

522.57 
462.98 
469.96 
500.90 


1,589 
1,843 
657 
1,357 
1,058 

5,027 
1,219 
1,406 
1,150 
1,451 

1,643 
1,485 
1,415 
1,228 
1,197 

1,965 
1,957 
1,801 
1,827 


216 
177 
148 
364 
210 

482 
49 
88 

208 
82 

198 
74 
166 
242 
149 

264 
392 
330 
111 


1,024 

1,229 

444 

940 

853 

5,177 

362 

243 

15,343 

170 

419 

256 

489 

2,031 

2,691 

753 
1,164 
1,368 

275 


234 
291 
124 
239 
191 

807 
136 
140 
1,023 
112 

244 
216 
206 
280 
344 

261 
337 
362 
211 


11 

5 

13 


137 

29 

255 


9 
20 

9 
13 
17 

128 
13 

7 
177 

6 

18 
27 
12 
13 
17 

11 
29 
21 
14 


3,220 
3,594 
1,650 
2,913 


Dorchester. . . . 

Essex 

Exeter 

Forest 

London 

Lucan 


99 
10 
51 


1 

3,382 

501 

1,068 

32 


2,330 

15,102 
2,290 
3,003 

17,933 
1,821 


Merlin 

Oil Springs. . . . 

Ridgetown 

St. Thomas. . . . 
Sarnia 

Strathroy 

Tillsonburg. . . . 
Wallaceburg . . . 
West Lome .... 


3 


396 


2,921 
2,058 


28 
11 


640 

14 

489 


2,956 
3,808 
4,898 

3,254 






3,879 


1 


362 
65 


4,245 
2,503 


Total 


7,572.82 


31,275 


3,950 


35,231 


5,758 


232 


7,371 


561 


84,378 


WEST CENTRAL 

Brantford 

Cayuga 

Clinton 

Dundas 

Elmira 

Guelph 

Kitchener 

Listowel 

Mitchell. . 


557.80 
531.96 
671.32 
375.05 
498.22 

394.43 
469.99 
629.59 
330.99 
801.05 

276.16 
513.12 


2,218 
1,993 
2,590 
1,746 
1,677 

1,346 
1,627 
2,658 
1,459 

3,477 

1,005 
2,177 


480 
282 
136 
293 
219 

312 
265 
107 
52 
946 

224 
165 


918 

845 

858 

3,951 

1,215 

1,526 

2,326 

627 

455 

2,434 

4,938 
795 


343 
290 
349 
349 
306 

247 
408 
330 
164 
506 

445 
289 


4 

23 

6 

"l5 
"l 


13 

1,617 

855 

3 

286 

17 
172 

74 


9 

29 
11 
42 

23 

11 

47 
17 
10 

25 

56 
16 


3,985 
5,079 
4,805 
6,384 
3,741 

3,459 
4,845 
3,815 
2,140 


Simcoe 

Stoney Creek. . 
Stratford. . . 


50 
1 


1,668 
130 


9,106 

6,799 
3,442 










Total 


6,049.68 


23,973 


3,481 


20,888 


4,026 


101 


4,835 


296 


57,600 



152 



Appendix HI — Rural 



Rural Power District 

MILES OF LINE, NUMBER OF CUSTOMERS 

as at December 31, 1960 





Miles of 

primary 

line 


Number of customers 


Rural operating 
areas by regions 


Farm 


Residential 


Com- 
mercial 


Summer 


Power 




Rural 


Hamlet 


Com- 
mercial 


Other 


Total 


Southern 
Ontario System 
— Continued 

NIAGARA 

Beamsville 

Dunnville 

St. Catharines. . 
Welland 


375.99 
278.99 
298.20 
475.93 


2,053 
1,081 
1,489 
1,369 


269 

275 
202 
485 


2,504 

731 

10,198 

7,872 


429 
231 
735 
837 


2 
55 

3 
30 


71 
1,257 

242 
822 


47 
15 
89 
95 


5,375 

3,645 

12,958 

11,510 


Total 


1,429.11 


5,992 


1,231 


21,305 


2,232 


90 


2,392 


246 


33,488 


CENTRAL 

Bowmanville. . . 

Brampton 

Markham 

Oshawa 

Richmond Hill. 

Sutton 

Woodbridge. . . . 


321.12 
557.45 
300.20 
286.02 
313.38 

353.74 
412.14 


972 
1,779 
976 
842 
951 

1,007 
1,274 


271 
847 
410 
390 
271 

305 
686 


1,031 
2,595 
4,331 
2,948 
7,423 

3,035 
3,221 


222 
422 
478 
360 
708 

371 
602 


27 
19 
29 
11 
4 

110 


106 
183 
483 
188 
188 

3,266 

77 


13 
86 
40 
36 
87 

22 
96 


2,642 
5,931 
6,747 
4,775 
9,632 

8,116 
5,956 


Total 


2,544.05 


7,801 


3,180 


24,584 


3,163 


200 


4,491 


380 


43,799 


GEORGIAN RAY 

Alliston 

Bala 

Barrie 

Bracebridge. . . . 
Cannington. . . . 

Huntsville 

Markdale 

Orangeville. . . . 

Orillia 

Owen Sound. . . 

Parry Sound. . . 
Penetanguishene 

Shelburne 

Stayner 

Uxbridge 

Walkerton 

Wingham 


498.77 
247.48 
515.47 
510.80 
498.21 

643.70 
656.85 
524.84 
605.25 
949.27 

474.57 
568.18 
725.81 
367.23 
508.60 

856.40 
702.06 


1,968 

10 

1,453 

309 

1,210 

659 
2,254 
1,404 
1,000 
2,514 

212 

970 

2,393 

1,179 

1,568 

3,163 
2,649 


293 
156 

554 
472 
276 

560 
185 
433 
474 
342 

439 
360 
189 
146 
310 

268 

85 


844 

566 

2,597 

1,055 

924 

1,357 
756 
1,295 
2,412 
1,585 

1,069 
1,017 
244 
1,131 
1,042 

802 
668 


244 
108 
440 
228 
250 

336 
321 
355 
463 

547 

264 
247 
230 
249 
289 

406 

338 


2 

94 

87 

125 

42 

175 

13 

9 

119 

154 

136 
155 

230 
26 

20 

28 


34 
2,682 
3,731 
3,401 
3,112 

2,824 

665 

475 

4,045 

3,597 

1,569 
5,718 
69 
3,410 
1,619 

769 
799 


16 

3 
23 

8 
12 

11 
15 
17 
15 

14 

7 

"3 
14 

15 
11 


3,401 
3,619 
8,885 
5,598 
5,826 

5,922 
4,205 
3,986 
8,530 
8,754 

3,703 
8,474 
3,125 
6,348 
4,868 

5,443 
4,578 


Total 


9,853.49 


24,915 


5,542 


19,364 


5,315 


1,415 


38,519 


195 


95,265 



Miles of Line and Number of Customers 



153 



Rural Power District 

MILES OF LINE, NUMBER OF CUSTOMERS 

as at December 31, 1960 





Miles of 

primary 

line 


Number of customers 


Rural operating 
areas by regions 


Farm 


Residential 


Com- 
mercial 


Summer 


Power 




Rural 


Hamlet 


Com- 
mercial 


Other 


Total 


Southern 
Ontario System 
— Concluded 
east central 

Bancroft 

Belleville 

Cobourg 

Fenelon Falls . . 
Frankford 

Kingston 

Lakefield 

Minden 

Napanee 

Norwood 

Peterborough . . 

Picton 

Tweed 


503.93 
214.43 
601.61 
543.40 
588.44 

884.68 
466.79 
520.78 
579.63 
392.83 

671.76 
474.45 
621.91 


611 

793 

1,693 

1,054 

1,990 

2,010 
558 
352 

1,928 
952 

1,789 
1,746 
1,152 


302 
209 
491 
120 
409 

534 
219 
311 
301 
172 

385 
387 

575 


1,221 
1,377 
1,449 
839 
1,405 

4,589 

669 

1,334 

1,242 

419 

2,590 

1,458 

781 


226 
245 
340 
276 
351 

720 
193 
342 
402 
139 

443 
303 
329 


71 

3 

74 

152 

36 

46 

97 

148 

38 
38 

72 

58 

123 


1,426 

48 

1,044 

3,719 

530 

1,714 
3,335 
3,723 
458 
1,306 

1,428 
799 
949 


6 

16 
15 
14 
12 

48 
1 
4 

12 
4 

30 

14 

3 


3,863 
2,691 
5,106 
6,174 
4,733 

9,661 

5,072 
6,214 
4,381 
3,030 

6,737 
4,765 
3,912 


Total 


7,064.64 


16,628 


4,415 


19,373 


4,309 


956 


20,479 


179 


66,339 


EASTERN 

Arnprior 

Brockville 

Cobden 

Delta 

Lancaster 

Merrickville . . . 

Ottawa 

Perth 

Plantagenet. . . . 
Vankleek Hill.. 

Winchester .... 


443.61 
612.50 
1,245.18 
462.43 
607.36 

296.90 
786.76 
870.44 
382.33 
223.70 

834.13 


1,018 
2,093 
2,522 
1,049 
2,250 

800 
2,404 
1,958 
1,554 

925 

3,327 


217 
488 
651 
255 
488 

167 
886 
390 
183 
92 

328 


1,131 
2,091 
3,535 
615 
1,399 

589 
9,312 
725 
833 
524 

1,665 


295 
469 
823 
260 

447 

150 
846 
375 
325 
191 

549 


40 
37 
117 
47 
15 

1 
10 
50 

3 
10 

2 


1,458 

996 

1,351 

1,389 

428 

245 

401 

2,026 

103 

80 

71 


22 
29 
34 
7 
35 

7 
96 
10 

25 
12 

43 


4,181 
6,203 
9,033 
3,622 
5,062 

1,959 
13,955 
5,534 
3,026 
1,834 

5,985 


Total 


6,765.34 


19,900 


4,145 


22,419 


4,730 


332 


8,548 


320 


60,394 



154 



Appendix III — Rural 



Rural Power District 

MILES OF LINE, NUMBER OF CUSTOMERS 

as at December 31, 1960 





Miles of 

primary 

line 


Number of customers 


Rural operating 
areas by regions 


Farm 


Residential 


Com- 
mercial 


Summer 


Power 




Rural 


Hamlet 


Com- 
mercial 


Other 


Total 


Northern 

Ontario 

Properties 
northeastern 

Algoma 

Kapuskasing. . . 

Kirkland Lake . 

Manitoulin .... 

Matheson 

New Liskeard. . 
North Bay .... 

Sudbury 

Timmins 

Warren 


325.39 
246.81 
118.03 
591.62 
496.56 

635.43 
826.78 
591.84 
83.09 
510.66 


380 
562 
92 
844 
941 

1,247 

1,098 

784 

147 

987 


169 
219 
76 
276 
284 

411 
782 
910 

28 
327 


3,971 
2,283 

236 
1,483 

668 

' 1,058 

3,539 

6,738 

678 

1,278 


643 

289 

80 

519 

225 

368 
571 
690 
76 
376 


44 
11 
19 
82 
9 

43 
143 

10 

1 

106 


293 
270 
349 
809 
318 

428 

1,320 

1,226 

85 

869 


75 
16 

3 
26 

6 

18 
45 
39 
12 
13 


5,575 
3,650 
855 
4,039 
2,451 

3,573 
7,498 
10,397 
1,027 
3,956 


Total 


4,426.21 


7,082 


3,482 


21,932 


3,837 


468 


5,967 


253 


43,021 


NORTHWESTERN 

Atikokan 

Dryden 

Fort Frances . . . 

Geraldton 

Kenora 

Port Arthur. . . . 
Terrace Bay . . . 


4.80 
338.25 
541.55 
134.81 
269.94 

872.31 
29.01 


"398 
911 

183 

1,724 


5 

378 

300 

15 

294 

926 
1 


57 
778 
525 
645 
650 

2,263 
556 


15 
248 
292 
215 
179 

435 
93 


1 
50 
42 

8 
130 

14 

1 


321 

109 

16 

912 

1,225 
11 


2 
11 

4 
19 
15 

25 

5 


80 

2,184 

2,183 

918 

2,363 

M 

6,612 

667 


Total 


2,190.67 


3,216 


1,919 


5,474 


1,477 


246 


2,594 


81 


15,007 



SUMMARY— MILES OF LINE, NUMBER OF CUSTOMERS 
as at December 31, 1969 





Miles of 


Number of customers 


System 




Residential 




Summer 






and Region 


primary 


























line 








Com- 


Com- 












Farm 


Rural 


Hamlet 


mercial 


mercial 


Other 


Power 


Total 


Southern 




















Ontario System 




















Western 


7,572.82 


31,275 


3,950 


35,231 


5,758 


232 


7,371 


561 


84,378 


West Central. . . 


6,049.68 


23,973 


3,481 


20,888 


4,026 


101 


4,835 


296 


57,600 


Niagara 


1,429.11 


5,992 


1,231 


21,305 


2,232 


90 


2,392 


246 


33,488 


Central 


2,544.05 


7,801 


3,180 


24,584 


3,163 


200 


4,491 


380 


43,799 


Georgian Bay . . 


9,853.49 


24,915 


5,542 


19,364 


5,315 


1,415 


38,519 


195 


95,265 


East Central. . . 


7,064.64 


16,628 


4,415 


19,373 


4,309 


956 


20,479 


179 


66,339 


Eastern 


6,765.34 


19,900 


4,145 


22,419 


4,730 


332 


8,548 


320 


60,394 


Total 


41,279.13 


130,484 


25,944 


163,164 


29,533 


3,326 


86,635 


2,177 


441,263 


Northern 




















Ontario 




















Properties 




















Northeastern. . . 


4,426.21 


7,082 


3,482 


21,932 


3,837 


468 


5,967 


253 


43,021 


Northwestern. . 


2,190.67 


3,216 


1,919 


5,474 


1,477 


246 


2,594 


81 


15,007 


Total ....... 


6,616.88 


10,298 


5,401 


27,406 


5,314 


714 


8,561 


334 


58,028 


Total— All systems 


47,896.01 


140,782 


31,345 


190,570 


34,847 


4,040 


95,196 


2,511 


499,291 



Comparative Annual Statistics 



155 



Rural Electrical Service 1951 - 1960 

CUSTOMERS, REVENUE, AND CONSUMPTION, BY CLASSES OF SERVICE 













Monthly 










Consump- 




consump- 


Average 


Class of service 


Year 


Revenue 


tion 


Customers 


tion per 
customer 


cost 
per kwh 






$ 


kwh 


No. 


kwh 


t 


*Farm 


1951 


8,097,710.92 


408,001,270 


123,434 


286 


1.98 




1952 


9,017,321.17 


465,813,826 


129,451 


307 


1.94 




1953 


11,053,487.41 


507,669,118 


133,522 


322 


2.18 




1954 


12,207,502.58 


558,217,490 


136,013 


345 


2.19 




1955 


12,915,852.58 


593,811,741 


138,648 


360 


2.18 




1956 


13,671,336.65 


642,704,082 


139,289 


385 


2.13 




1957 


14,386,097.14 


685,873,991 


140,604 


408 


2.10 




1958 


15,159,553.04 


739,105,332 


140,343 


439 


2.05 




1959 


16,122,453.84 


804,044,121 


140,892 


477 


2.01 




1960 


16,688,958.79 


850,192,892 


140,782 


503 


1.96 


*Hamlet & Rural 


1951 


6,380,808.20 


308,065,399 


124,091 


214 


2.07 


Residential 


1952 


7,253,640.00 


359,033,745 


133,193 


233 


2.02 




1953 


9,560,018.46 


421,976,886 


150,627 


248 


2.27 




1954 


11,194,393.02 


497,941,047 


160,552 


267 


2.25 




1955 


12,734,130.77 


577,738,311 


177,398 


285 


2.20 




1956 


14,639,910.88 


689,671,299 


181,113 


321 


2.12 




1957 


16,174,554.38 


780,555,465 


196,025 


345 


2.07 




1958 


17,732,046.03 


905,276,590 


207,570 


374 


1.96 




1959 


18,862,773.02 


988,315,209 


218,287 


387 


1.91 




1960 


20,151,434.03 


1,070,637,716 


221,915 


405 


1.88 


""Commercial 


1951 


2,284,851.74 


114,818,736 


20,110 


504 


1.99 


(Including Summer 


1952 


2,457,032.13 


125,448,544 


24,564 


468 


1.96 


Commercial) 


1953 


3,385,239.46 


148,684,777 


28,870 


464 


2.28 




1954 


3,707,824.28 


165,641,656 


30,403 


466 


2.24 




1955 


3,996,936.76 


186,152,293 


32,509 


493 


2.15 




1956 


4,444,185.15 


210,438,942 


33,481 


532 


2.11 




1957 


4,855,540.79 


232,393,971 


35,179 


564 


2.09 




1958 


5,346,040.16 


259,521,563 


36,966 


600 


2.06 




1959 


5,764,611.07 


282,562,584 


38,176 


627 


2.04 




1960 


6,099,889.90 


301,874,591 


38,887 


653 


2.02 


*Summer 


1951 


1,616,368.92 


36,502,195 


49,913 


65 


4.43 




1952 


1,826,359.64 


40,160,959 


55,159 


64 


4.55 




1953 


1,833,881.12 


34,136,058 


57,547 


51 


5.37 




1954 


2,034,199.00 


38,459,711 


62,183 


54 


5.29 




1955 


2,214,360.48 


40,375,690 


68,600 


51 


5.48 




1956 


2,478,450.51 


45,989,565 


74,390 


54 


5.39 




1957 


2,709,831.47 


50,673,331 


79,792 


55 


5.35 




1958 


2,943,051.21 


55,170,379 


85,611 


56 


5.33 




1959 


3,170,306.65 


60,345,721 


91,390 


57 


5.25 




1960 


4,141,665.36 


67,785,615 


95,196 


61 


6.11 


Industrial Power. . . . 


1951 


1,562,608.29 


87,692,082 


1,058 


7,067 


1.78 




1952 


1,799,924.89 


102,608,301 


1,170 


7,676 


1.75 




1953 


2,147,899.48 


121,310,479 


1,289 


8,222 


1.77 




1954 


2,545,737.21 


148,176,508 


1,466 


8,964 


1.72 




1955 


2,934,852.81 


171,202,169 


1,681 


9,067 


1.71 




1956 


3,402,416.31 


207,252,224 


1,782 


9,975 


1.64 




1957 


3,732,252.41 


225,748,793 


2,011 


9,920 


1.65 




1958 


4,410,317.84 


278,005,882 


2,113 


11,235 


1.59 




1959 


4,612,172.64 


287,458,107 


2,325 


10,795 


1.60 




1960 


5,017,774.81 


325,416,458 


2,511 


11,215 


1.54 



Beginning in 1959, consumption for flat-rate water-heaters was estimated on the basis of 16.8 hours' daily 
instead of 20 hours' daily use as previously. The data for previous years have been adjusted to the new basis. 



APPENDIX IV— LEGISLATIVE 

AT the 1960 Session of the Legislative Assembly of the Province of Ontario 
one Act respecting The Hydro-Electric Power Commission of Ontario was 
passed. The said Act is reproduced here in full. The short title of the Act 
is as follows: 

The Power Commission Amendment Act, 1960, Chapter 85. 

ACT 

CHAPTER 85 

An Act to amend The Power Commission Act 

Assented to April 12th, 1960. 
Session Prorogued April 12th, 1960. 

ITER MAJESTY, by and with the advice and consent of the 
■*- -*- Legislative Assembly of the Province of Ontario, enacts as 
follows: 

e.'28i,'s. it! !• Section 17 of The Power Commission Act is repealed and the 
re-enacted following subs tituted therefor: 

156 



The Power Commission Amendment Act, 1960 157 

17. The Commission shall set apart annually as a sinking fund, fund ing 

(a) such sums as are received by the Commission from 
municipal corporations under clause c of section 74, 
and section 75, and, subject to subsection 2 of section 
84, such sums as are appropriated by the Commission 
for sinking fund purposes out of the revenues received 
from the supply of power under section 68 to persons 
within the area of a municipal corporation that has 
contracted with the Commission for a supply of power 
at cost; 

(b) such sums as are appropriated by the Commission 
for sinking fund purposes out of the revenues received 
from the supply of power in rural power districts; 

(c) such sums as are appropriated by the Commission 
for sinking fund purposes for the repayment of any 
indebtedness incurred or assumed by the Commission 
in respect of the cost of administrative service build- 
ings and equipment, and for the restoration of any 
reserve or other funds of the Commission utilized for 
the payment of the cost thereof. 

2. Subsection 7 of section 20 of The Power Commission Act isR.s.o. 1950, 
amended by adding at the end thereof "and such fund may be in- subs, i, 

e\ tti p n ci p ci 

vested in investments authorized by section 207 of The Corporations 
Act, 1953 for joint stock insurance companies", so that the subsection 
shall read as follows: 

(7) The fund shall be maintained and administered by the Adminis- 

„ .. ,. i ^ .. r ... tration and 

Commission and the cost to the Commission ol maintaining investment 
and administering it shall be deemed to be part of the cost 
of the administration of the Commission and shall be charge- 
able accordingly, and such fund may be invested in invest- 
ments authorized by section 207 of The Corporations Act, 1953, c. 19 
1953 for joint stock insurance companies. 

3. Section 23 of The Power Commission Act is repealed. R §i9* 19 o2' 

C . ^01, S. ^o , 

repealed 

4. — (1) Subsection 5 of section 32 of The Power Commission Act n -S£>- 19 go, 
is repealed and the following substituted therefor: subs - 5 V , 

(5) The Lieutenant Governor in Council may from time to time Appointment 
appoint a board of valuation consisting of as many members powers of 
as he from time to time determines, one of whom shall be valuation 
named chairman, who shall receive their reasonable and 
necessary travelling and other expenses and such fees as 



1 58 Appendix IV — Legislative 

may be fixed by the Lieutenant Governor in Council, and 
the same shall be paid by the Commission as part of its 
general administration expense, and, when no agreement is 
arrived at as to the amount of compensation to be paid 
to the owner, the board of valuation shall, as soon as con- 
veniently may be after a request to them either from the 
owner or the Commission, secure from the Commission a 
description of the land, right or easement that the Com- 
mission requires or has taken from the owner and make 
such inquiries and inspection and procure such expert advice 
as they may think desirable and in accordance with sub- 
section 3 fix and determine the compensation to be paid for 
such land, right or easement, or property damage, and 
notify by registered letter the owner and the Commission 
of such finding, and three members of the board of valuation 
shall form a quorum and be sufficient for the exercise of all 
the jurisdiction and powers of the board. 

cVis?,' s. 9 32! (2) Subsection 6 of the said section 32 is amended by striking 
amended out "30" in the third line and inserting in lieu thereof "sixty" and by 

striking out "valuator" in the fourth line and inserting in lieu thereof 

"board of valuation". 



28?,' s. 9 32i (3) Subsection 7 of the said section 32 is amended by striking 
out "valuator" in the first line and inserting in lieu thereof "board of 
valuation". 



R.S.O. 1950, 
c 

subs. 7, 
amended 



?'28?,* s 9 32; (4) Subsection 9 of the said section 32 is amended by striking 
amended ou t "valuator" in the third and fifth lines respectively and inserting 
in lieu thereof "board of valuation". 

S*28i," s. 9 !?! (5) Subsection 10 of the said section 32 is amended by striking 
amended out "valuator" in the fourth line and inserting in lieu thereof "board 
of valuation". 

cVfsi,' s. 9 32! (6) Subsection 11 of the said section 32, as amended by subsection 2 
amended °^ sec tion 3 of The Power Commission Amendment Act, 1956, is further 

amended by striking out "valuator" in the sixth line and inserting in 

lieu thereof "board of valuation". 

r^Jsf.'s 1 ^,' **• Subsection 2 of section 35 of The Power Commission Act is 

arnended amended by striking out "valuator" in the fourth, fifth and tenth 

lines respectively and inserting in lieu thereof "board of valuation". 

c.'28i; s. 52,' 6. — (1) Section 52 of The Power Commission Act is amended by 
inserting after "Ontario" in the eighth line "or the Deputy Provincial 
Treasurer", so that subsection 1 of the said section shall read as 
follows: 






amended 



The Power Commission Amendment Act, I960 159 

(1) The Lieutenant Governor in Council is authorized, on such Sg a bonds 6 of 
terms as may be approved by Order in Council, to agree to Commisslon 
guarantee the payment of the principal and interest of any 
bonds, debentures and other securities issued by the Com- 
mission, and the form and manner of any such guarantee 
or guarantees shall be such as the Lieutenant Governor in 
Council may approve, and the guarantee or guarantees shall 
be signed by the Treasurer of Ontario or the Deputy Pro- 
vincial Treasurer, or such other officer or officers as may be 
designated by the Lieutenant Governor in Council, and, 
upon being so signed, the Province of Ontario shall become 
liable for the payment of the principal and interest of the 
bonds, debentures and securities guaranteed, according to 
the tenor thereof, and the Lieutenant Governor in Council 
is authorized to make arrangements for supplying the money 
necessary to fulfil the requirements of the guarantee or 
guarantees, and to advance the amount necessary for that 
purpose, out of the public funds of the Province, and, in 
the hands of any holder of any such bonds, debentures or 
securities, any guarantee so signed shall be conclusive 
evidence that the terms of this section have been complied 
with. 



(2) The said section 52 is further amended by adding thereto R.s.o. 1950, 

,;,,.,. c. 281, s. 52, 

the following subsection: amended 

(2) The signature of the Treasurer of Ontario or of the Deputy Signatures 
Provincial Treasurer or of such other officer or officers mechanically 
provided for in subsection 1 may be engraved, lithographed, 
printed or otherwise mechanically reproduced, and the 
mechanically-reproduced signature of any such person shall 
be deemed for all purposes the signature of such person and 
shall be binding upon the Province of Ontario notwith- 
standing that the person whose signature is so reproduced 
may not have held office at the date of the bonds, debentures 
or other securities or at the date of the delivery thereof and 
notwithstanding any change in any of the persons holding 
any such office between the time when any such signature is 
affixed and the date of delivery of the bonds, debentures 
or other securities. 



7. The Power Commission Act is amended by adding thereto the^-f^- 195 °- 

following section: amended 

58a. Section 301 of The Municipal Act does not apply to any £243; 1950, 
contract between the Commission and a municipal corpora- not°to 
tion for the supply of power. apply 



160 



Appendix IV — Legislative 



R.S.O. 1950, 
c. 281, s. 68, 
subs. 3, 
re-enacted 



8. Subsection 3 of section 68 of The Power Commission Act is 
repealed and the following substituted therefor: 



Application 
of net 
surplus 



(3) Any net surplus made by the Commission in supplying 
power under subsection 1 to persons within the areas of 
municipal corporations and police villages excluded from 
the Southern Ontario Rural Power District by subsection 2 
of section 84 that have contracted with the Commission 
for the supply of power at cost shall be applied in reduction 
of the cost of power to such municipal corporations and 
police villages; and subject to subsection 3 of section 59a 
any net surplus made by the Commission in supplying 
power under subsection 1 to other persons shall be applied 
in reduction of the cost of power in rural power districts. 



9. Section 81 of The Power Commission Act, as re-enacted by 



R.S.O. 1950, 
c. 281, s. 81 

cock's. 2), section 2 of The Power Commission Amendment Act, J 958, is amended 
amended by a( jding thereto the following subsection: 



Power of 

township 

to extend 

application 

of street 

lighting 

agreement 



(5a) Where under this section a township has entered into a 
contract with the Commission for the lighting of streets 
in one or more areas, the township may from time to time, 
without petition and without the assent of the electors, 
pass a similar by-law to provide that the contract shall also 
apply to any other street lighting area or areas in the 
township. 



10. Subsection 2 of section 84 of The Power Commission Act is 



R.S.O. 1950, 
c. 281, s. 84, 

re-enacted repealed and the following substituted therefor: 



Defining 

power 

districts 



(2) There shall be two rural power districts, namely, 



(a) the Northern Ontario Rural Power District comprising 
the Northeastern and Northwestern Regions as 
defined from time to time by the Commission; and 

(b) the Southern Ontario Rural Power District comprising 
the remaining territory of Ontario, 



and there shall be excluded from each of the rural power 
districts the areas of all municipal corporations and police 
villages that have contracted with the Commission for the 
supply of power at cost under section 58, 59, 63 or 66, or 
that hereafter so contract, except that all persons who are 



The Power Commission Amendment Act, 1960 



161 



supplied with power under section 68 and who are within 
the area of any such municipal corporation excluded from the 
Northern Ontario Rural Power District shall be deemed to 
be within the Northern Ontario Rural Power District. 

11. This Act shall be deemed to have come into force on the 1st Commence- 

ment 

day of January, 1960. 

12. This Act may be cited as The Power Commission Amendment short title 
Act, 1960. 



ORDER IN COUNCIL 

The agreements between The Hydro-Electric Power Commission of Ontario 
and municipalities and corporations mentioned in the list hereunder given were 
approved by Order in Council. 



City 
North Bay Jan. 7, 1960 

Towns 

Cache Bay Jan. 5, 1960 

Capreol Mar. 29, 1960 

Cochrane Feb. 9, 1960 

Espanola Nov. 27, 1959 

Latchford Jan. 5, 1960 

Massey Oct. 21, 1960 

Thessalon Feb. 1, 1960 

Webbwood Nov. 23, 1960 



Village 
Beachburg Nov. 10, 1960 

Townships 

Larder Lake Feb. 23, 1960 

West Ferris Oct. 21, 1960 



Improvement District 



McGarry Jan. 5, 1960 



162 



Appendix IV — Legislative 



Corporations 

Agnico Mines Limited May 

Aluminum Company of Canada, Limited Oct. 

Avro Aircraft Limited Nov. 

Beaver Wood Fibre Company Limited Mar. 

Beaver Wood Fibre Company Limited Mar. 

Brockville Chemicals Limited Aug. 

Burlington Steel Company Limited Aug. 

Canada Starch Company, Limited Nov. 

Canadian Industries, Limited May 

Canadian Johns-Manville Company Limited June 

Canadian Niagara Power Company, Limited April 

Consolidated Mosher Mines Limited Oct. 

Consolidated Sand & Gravel, Limited May 

Cyanamid of Canada Limited Aug. 

Deer Horn Mines Limited May 

Denison Mines Limited Aug. 

Dominion Tar & Chemical Company June 

Du Pont of Canada Limited Sept. 

Exolon Company Mar. 

Ford Motor Company of Canada, Limited Dec. 

Glen Lawrence Construction Company Sept. 

Hayes Steel Products Limited May 

Imperial Oil Limited Jan. 

Imperial Oil Limited Jan. 

Kam-Kotia Porcupine Mines, Limited April 

Lindsay Explorations Limited Oct. 

National Harbours Board June 

Neelon Steel Limited Dec. 

Niagara Mohawk Power Corporation April 

Norton Company Nov. 

Orenda Engines Limited April 

Pembroke Electric Light Company Limited Sept. 

Pronto Uranium Mines Limited April 

Silver-Miller Mines Limited Nov. 

Sun-Canadian Pipe Line Company Limited Jan. 

Sun-Canadian Pipe Line Company Limited Jan. 

Young, H. G., Mines Limited June 



25 


1960 


6 


1960 


9 


1960 


29 


1960 


29 


1960 


31 


1960 


15 


1960 


9 


1960 


3 


1960 


2 


1960 


1 


1960 


27 


1960 


12 


1960 


31 


1960 


10 


1960 


24 


1960 


2 


1960 


9 


1960 


18 


1960 


20 


1960 


9 


1960 


9 


1960 


12 


1960 


21 


1960 


19 


1960 


3 


1960 


11 


1960 


2 


1960 


1 


1960 


2 


1960 


1 


1960 


16 


1960 


4 


1960 


16 


1960 


21 


1960 


21 


1960 


7 


1960 



SUPPLEMENT 



MUNICIPAL ELECTRICAL SERVICE 



v I ^HIS supplementary section on service in the municipal systems brings 
-■- together statistical information on retail service to customers served by the 
354 municipal electrical utilities and the 28 Commission-owned local systems. 
The number of residential, commercial, and industrial power service customers 
so supplied increased by 42,801 during 1960 and at December 31 stood at 
1,381,957. 

The numbers in the various customer groups that contribute to this total 
reflect reclassifications of customers being made in conjunction with the intro- 
duction of new rate schedules. The purpose of these reclassifications is that 
certain industrial power customers, for example small processing companies such 
as dairies and bakeries, shall be classified as commercial service, and that com- 
mercial service customers with connected loads of less than 5 kilowatts may be 
billed under residential service. The table on page 164 provides some indication 
of the growth in residential, commercial, and industrial power service over a 
10-year period. The statistical information relative to energy consumption and 
unit cost for these three main classes of service is reproduced in the graphs on 
page 165. 

The revenues derived from street lighting are based on estimated consump- 
tion only (see table on page 96), and the revenue applicable to the municipal 
utilities is given in the analysis of revenue and expense that follows. In each 
of the operating statements of the utilities the revenue from street lighting is 
included in the amount shown for sales of electric energy. It can be derived 
for any utility by subtracting from the revenue shown in Statement "B" the sum 
of the revenues for the same utility shown in Statement "D". 

163 



164 



Municipal Electrical Service 



MUNICIPAL ELECTRICAL UTILITIES 

Total revenues of the municipal electrical utilities during 1960 were 
$189,320,571. Comparative figures for previous years are given in the table 
on page 170. The 1960 total revenues show an increase of 6.3 per cent over the 
total revenues for 1959. 

The increase in total revenues was almost entirely due to increased revenues 
from the sale of electric energy, which amounted to $186,599,701 and consisted 
of $76,509,879 (41.0 per cent) from residential customers, $40,310,556 (21.6 per 
cent) from commercial customers, $63,805,494 (34.2 per cent) from industrial 
power customers, and $5,973,772 (3.2 per cent) from street lighting service to 



Municipal Electrical Utilities and Local Systems 

CUSTOMERS, REVENUE, AND CONSUMPTION 
1951 to 1960 













Monthly 


Average 


Service 


Year 


Revenue 


Consumption 


Customers 


consump- 
tion per 
customer 


cost 
per kwh 






$ 


kwh 


No. 


kwh 


i 


Residential 


1951 


32,905,664 


3,065,257,438 


800,033 


319 


1.07 




1952 


36,811,115 


3,411,685,705 


836,802 


340 


1.08 




1953 


44,647,668 


3,734,160,562 


877,323 


355 


1.20 




1954 


50,833,346 


4,246,511,375 


930,674 


380 


1.20 




1955 


55,241,247 


4,667,789,930 


970,829 


401 


1.18 




1956 


61,234,494 


5,191,581,628 


1,031,482 


419 


1,18 




1957 


65,842,103 


5,602,672,756 


1,072,868 


435 


1.18 




1958 


69,804,608 


6,036,470,489 


1,139,061 


442 


1.16 




1959 


73,955,229 


6,540,969,291 


1,194,878 


456 


1.13 




1960 


78,337,615 


6,944,659,090 


1,234,903 


469 


1.13 


Commercial 


1951 


17,549,402 


1,249,185,273 


111,154 


937 


1.40 




1952 


19,502,920 


1,387,136,211 


115,304 


1,003 


1.41 




1953 


23,603,194 


1,526,535,177 


119,498 


1,065 


1.55 




1954 


26,293,250 


1,694,071,712 


123,884 


1,140 


1.55 




1955 


28,576,115 


1,858,974,388 


127,913 


1,211 


1.54 




1956 


31,423,691 


2,081,200,929 


127,497* 


1,360 


1.51 




1957 


33,901,487 


2,270,913,902 


124,757* 


1,517 


1.49 




1958 


35,968,060 


2,445,225,765 


122,446* 


1,664 


1.47 




1959 


38,079,501 


2,669,327,226 


120,733* 


1,842 


1.43 




1960 


41,229,320 


2,921,670,317 


123,441* 


1,972 


1.41 


Industrial Power 


1951 


29,353,071 


3,459,742,798 


19,370 


14,884 


0.85 




1952 


31,403,227 


3,619,518,306 


20,055 


15,040 


0.87 




1953 


38,482,884 


3,948,124,809 


20,885 


15,753 


0.98 




1954 


40,855,075 


4,089,513,923 


21,671 


15,726 


1.00 




1955 


44,270,882 


4,637,527,118 


22,237 


17,379 


0.96 




1956 


47,808,610 


5,140,704,025 


22,809* 


18,782 


0.93 




1957 


50,124,976 


5,366,245,253 


22,607* 


19,781 


0.93 




1958 


52,741,979 


5,651,743,390 


23,077* 


20,409 


0.93 




1959 


61,167,603 


7,052,152,034 


23,545* 


24,960 


0.87 




1960 


64,057,506 


7,326,683,025 


23,613* 


25,857 


0.87 



* Normal year-to-year increases in number of customers are obscured in these years by reclassifi- 
cations from commercial to residential and from industrial power to commercial service billing. 
Note: Kwh consumption figures for residential and commercial services in the above table 
reflect the use of flat-rate water-heaters for a uniform average of 16.8 hours per day. 



Consumption and Average Cost per Kilowatt-hour 



165 



MUNICIPAL ELECTRICAL UTILITIES AND LOCAL SYSTEMS 
ANNUAL ENERGY CONSUMPTION AND AVERAGE COST PER KILOWATT-HOUR 

RESIDENTIAL SERVICE 



CENTS PER KWh 
2.0 



INDUSTRIAL POWER SERVICE 

BILLION KWH CENTS PER KWH 
8 2.0 



































n 


















IN 


UA 


L 


30 


NS 


ur* 


1PT 


ON 










Ar 




































ANNUAL CONSUMPTION 



1950 



1955 



1960 



1960 



COMMERCIAL SERVICE 

CENTS PER KWH BILLION KWH 

2.0 8 40 



AVERAGE COST/ 



TOTAL ANNUAL ENERGY 
CONSUMPTION 



ANNUAL CONSUMPTION n 



nr 

1950 



T 

1955 



ANNUAL CONSUMPTION 

(Includes street lighting) 



r 

I960 



T 

1950 



T 

1955 



- - - 10 



166 



Municipal Electrical Service 



municipalities. Increases in revenue from residential and industrial power 
customers of 5.9 per cent and 4.8 per cent generally reflect corresponding in- 
creases in energy consumption so that the average cost per kilowatt-hour to the 
customer remained unchanged. Revenue from commercial customers increased 
by 8.4 per cent, or somewhat less than the increase in energy consumption, with 
the result that the average cost per kilowatt-hour to the customer declined. 

Total expenses of $175,423,661 were 9.2 per cent higher than in 1959, and 
this increase was only partially offset by the increase in revenues. The net 
income for 1960 was $13,896,910, or 7.3 per cent of total revenue as compared 
with 9.8 per cent in 1959. 



Summary of Financial Position 

Total assets, after deducting accumulated depreciation, were $645,644,451, 
of which $261,101,650 had been contributed through the cost of power for the 



MUNICIPAL ELECTRICAL UTILITIES 

REVENUE 



MILLION 
DOLLARS 



175 



125 



100 




Commercial service 
Street lighting 

and Other 



1955 



MILLION 
DOLLARS 



Municipal Electrical Utilities — Financial Position 



167 



retirement of the Commission's long-term debt. This amount, therefore, re- 
presents the utilities' equity in the Commission's power systems. It differs 
from the sum of the sinking fund reserves shown as contributed by the utilities 
on the Commission's balance sheets only because most of the utilities close their 
books before the Commission's calculation of sinking fund for the year is available. 
Their balance sheet figures for the equity account are therefore for the most part 
one year in arrears. 

The investment of the municipal utilities in fixed assets at cost increased 
by $28,192,683 to reach $413,611,989, against which accumulated depreciation 
of $82,246,973 had been provided. Net long-term debt, that is debentures 
outstanding less local sinking fund provisions, increased by $3,382,064 to 
$72,112,726 at December 31, 1960. The net long-term debt amounted to 17.4 
per cent of the cost of fixed assets. 



MUNICIPAL ELECTRICA 

FIXED ASSETS AND LONG-^ 


L UTILITIES 

rERM DEBT 

MILLION 
DOLLARS 
-J 














FIXED ASSETS AT C 


OST 


n 




pi 








LONG-TERM 

DEBT -~--*.-.^ 


/ 

n 


1 1 1 

1940 1945 1950 


I I 

1955 I960 



168 Municipal Electrical Service 

Municipal Retail Rates 

Under The Power Commission Act the Commission exercises supervisory 
control over the activities of the municipal electrical utilities, and their rates to 
ultimate customers are subject to the Commission's approval. The rates set 
will usually provide for some margin of net income in addition to providing for 
the operating expenses of the utility. 

A margin of net income provides both an economical source of funds for 
normal system expansion and a stabilizing factor in retail rate adjustment, and 
the Commission takes this into consideration when reviewing municipal retail 
rates. 

FINANCIAL AND OTHER STATISTICAL TABLES 

Four statistical tables complete this municipal service supplement. The 
first two, designated ''Statements A and B" and summarized on page 171, deal 
with accounting operations of the 354 municipal electrical utilities. These 
statements are the balance sheets and operating statements of the utilities 
alphabetically arranged for the Southern Ontario System and the Northern 
Ontario Properties. The other two statements, designated "Statement C" and 
"Statement D", give rates and statistics for each of the 354 utilities and 28 
Commission-owned local systems. Both statements are alphabetically arranged. 
The rate schedules in Statement "C" are supplemented by typical monthly 
bills for selected levels of consumption to facilitate comparison of the cost of 
service in different municipalities. Statement "D" gives information supple- 
mentary to that given in Statement "B" regarding customers, revenue, and 
consumption, both total and average per customer, as well as average unit costs 
for the three main classes of service. The population figures given are for the 
most part those recorded in the Municipal Directory for 1961 published by the 
Department of Municipal Affairs of Ontario. 



MUNICIPAL ELECTRICAL SERVICE 



Statistical Tables 



STATEMENTS A and B— 

Financial Statements of the Municipal Electrical Utilities 

Consolidated for Years 1951 to 1960 Page 170 

By Municipalities Page 172 



STATEMENT C— 

Rates and Typical Bills for Electrical Service Provided by the 

354 Municipal Electrical Utilities and 28 Local Systems Page 222 



STATEMENT D— 

Customers, Revenue, and Consumption in Municipalities Served by 

the 354 Municipal Electrical Utilities and 28 Local Systems Page 244 



169 



170 



Municipal Electrical Service 

MUNICIPAL ELECTRICAL UTILITIES 



Year 


1951 
324 


1952 
327 


1953 
332 


1954 


Number of municipalities included 


338 


A. BALANCE SHEETS 

FIXED ASSETS 


$ 

173,722.457 
48,087,417 


$ 

193,795,886 

50,985,329 


$ 

214,595,382 

54,282,571 


$ 
243,525,700 




58,973,786 








125.635.040 

3,276,779 

16,291,593 

7.727,033 


142.810,557 

4,667,729 

11,542,720 

7,386,628 


160,312,811 

4,884,136 
10.716,659 
10,298,699 


184,551,914 


CURRENT ASSETS 


7,376,869 




16,361,137 
10,695,799 








27.295,405 

7,514,369 

613,435 

1,636,237 


23,597,077 

8.001,403 

388,410 

1,889,669 


25,899,494 

7.527.844 

410,806 

2,393,860 


34,433,805 


OTHER ASSETS 


7,413,229 


Sinking fund on local debentures 


383.454 
3,465,797 








9,764,041 
118,269,171 


10,279,482 
128,655,935 


10,332,510 
140,068,857 


11,262,480 


Equity in Ontario Hydro Systems 


152,461,822 




280,963,657 


305,343,051 


336,613,672 


382,710,021 


LIABILITIES 

Debentures outstanding. 


18,889,520 
9,738,476 
1.612.914 


24,159,239 

10.375.202 

1,762,833 


29,827,723 

10,943,035 

2,224,181 


45,645,051 
11,090 473 


Accounts payable. . 


Other 


2,843,742 




Total liabilities 


30,240,910 

118,269,171 
5,628,317 


36,297,274 

128,655,935 
8,008,752 


42,994,939 

140,068,857 
8,153,001 


59,579,266 

152,461,822 
8.095,705 


RESERVES 

Equity in Ontario Hydro Systems. . . . 
Other 




Total reserves 


123,897,488 

59.434,312 
613,435 

67,511,315 

733,803 


136,664,687 

60,260,350 
388,410 

72,374,288 

641,958 


148,221,858 

61,417,714 
410,806 

83,934,775 

366,420 


160 557 527 


CAPITAL 

Debentures redeemed 


64 210 220 


Local sinking fund 


383 454 


Accumulated net income invested in 
plant or held as working funds. . . 

Frequency standardization expense 
charged this year 


98,687,493 
707,939 






Total capital 


126,825,259 


132,381,090 


145,396,875 


162 573 228 








280,963,657 


305,343,051 


336,613,672 


382,710,021 


B. OPERATING STATEMENTS 

REVENUE 

Sales of electric energy 


80.964.214 
1,347,467 


88,744,441 
1,314,598 


107,997,010 
1,257,311 


119 510 834 


Other 


1,345,281 




Total revenue. . 


82,311,681 


90,059,039 


109,254,321 


120,856,115 




EXPENSE 

Power purchased 


50,854.323 
290.579 
8,886,314 
7,283,472 
1,524,931 
4,717,497 
87,225 


55,583,501 
322,179 
9,918,638 
7,645,806 
1,981,386 
5,293,509 
71,211 


69,750,630 

319,744 

10,674,897 

8,236,239 

2,400,468 

5,832,594 

147,083 


75.589,512 
426,606 

11,527,269 
9,299,705 
3,242,705 
6 547,361 


Local generation 


Operation and maintenance 


Administration 


Fixed charges — interest and principal . . 
— depreciation 




141,824 






73,644,341 


80,816,230 


97,361,655 


106,774,982 




Net Income or net expense 


8,667,340 


9,242,809 


11,892,666 


14,081,133 




Number of customers 


904,880 


941,975 


986,144 


1,045,742 



Statements A and B 
CONSOLIDATED FINANCIAL STATEMENTS 1951-1960 



171 



1955 


1956 


1957 


1958 


1959 


1960 


343 


350 


351 


354 


354 


354 


$ 


$ 


$ 


$ 


$ 


$ 


267,090,752 


298.832,207 


327,925,974 


349,706,161 


385,419,306 


413,611,989 


62,413,111 


66,539,420 


68,975,083 


72,673,866 


77,551,575 


82,246,973 


204,677.641 


232,292,787 


258,950,891 


277,032,295 


307,867,731 


331,365,016 


9,277,807 


9,858,536 


10,819,896 


10,769,037 


10,400,010 


12,250,801 


17,392,469 


15,512,896 


14,174,408 


13.333,906 


15,560,183 


13,990,120 


9,939,403 


12.776,466 


12,573,922 


13,911,267 


13,463,791 


12,868,807 


36,609.679 


38,147,898 


37,568,226 


38.014,210 


39,423,984 


39,109,728 


7,900,466 


9,681,858 


9,579,584 


17,237,653 


9,381,215 


9,197,511 


383,751 


290,682 


561,622 


1,033,436 


1,726,182 


2.316,958 


2,323,308 


2,399,184 


1,894,582 


2,214,392 


2,421,279 


2,553,588 


10,607,525 


12,371,724 


12,035,788 


20,485,481 


13,528,676 


14,068,057 


167,250,921 


183.262,708 


200,293,236 


218,736,441 


238,790.589 


261,101,650 


419,145,766 


466,075,117 


508,848,141 


554,268,427 


599,610,980 


645,644,451 


49.776,907 


58,528,557 


63,315,360 


69,363,792 


70,456,844 


74,429,684 


10,574,522 


11,633,156 


11,226,905 


10,105,465 


10,589,995 


10,485,382 


3,493,146 


3,910,276 


4.207,237 


6,175,200 


6,565,031 


7,146,524 


63,844,575 


74,071,989 


78.749,502 


85,644,457 


87,611,870 


92,061,590 


167,250,921 


183,262,708 


200,293,236 


218,736,441 


238,790,589 


261,101,650 


7,765,477 


6,948,236 


5,658,849 


3,507,375 


2,864,918 


2,920,005 


175,016,398 


190,210,944 


205,952,085 


222,243,816 


241,655,507 


264,021,655 


66,488,672 


69,338,990 


72,087,556 


75,021,200 


77,881,620 


81.266,027 


383,751 


290,682 


561,622 


1,033,436 


1,726,182 


2,316,958 


114,727.112 


132,983,134 


152,057,614 


170,871,551 


190,444,985 


205,984,657 


1,314,742 


820,622 


560,238 


546,033 


290,816 


6,436 


180,284.793 


201.792.184 


224,146,554 


246,380,154 


270,343,603 


289,561,206 


419,145,766 


466,075,117 


508,848,141 


554,268,427 


599,610,980 


645,644,451 


129,810,298 


142,629,092 


151,855,664 


160,700,759 


175,686,813 


186,599,701 


1,457,199 


1,554,347 


1,580,224 


1,723,986 


2,400,070 


2,720,870 


131,267,497 


144,183,439 


153,435,888 


162,424,745 


178,086,883 


189,320,571 


79,779,898 


87,344,024 


92,682,089 


98,563,451 


111,160,867 


122,634,361 


459,594 


501,386 


575,771 


509,240 


531,076 


536,118 


12,076,620 


13,406,955 


14,362,587 


15,544,060 


17,065,080 


18,273,164 


9,896,805 


11.015,893 


12,086,583 


13,654,386 


14,954,828 


15,766,246 


4,216,877 


4,744,936 


5,504,842 


6,175,773 


6,824,770 


7,440,556 


7,193,495 


7,709,546 


8,389,004 


9,216,594 


10,030,350 


10.750,710 


144,121 


59,374 


53,525 


13,060 


14,316 


22,506 


113,767,410 


124,782,114 


133,654,401 


143,676,564 


160,581,287 


175,423,661 


17,500,087 


19,401,325 


19,781,487 


18,748,181 


17,505,596 


13,896,910 


1,089,835 


1,153,371 


1,192,357 


1,255,805 


1,310,099 


1.351,915 



172 



Southern Ontario System 



Municipal Electrical Service 

Municipal Electrical Utilities Financial 





Acton 
4,336 


Ailsa Craig 
541 


Ajax 
7,937 


Alexandria 
2,451 


Alfred 
915 






2.904 






A. BALANCE SHEETS 

FIXED ASSETS 


$ 
371,212 
35,160 


$ 

39.582 
1,237 


$ 
850,322 
149,493 


$ 
247,925 
59,933 


$ 

73.924 

17,063 


$ 
187,579 




37,664 








336,052 

13,594 
3.000 
2,832 


38,345 
6,401 


700.829 
47.367 


187,992 

4,393 
13,000 
4,107 


56.861 
8,023 


149,915 


CURRENT ASSETS 


9,007 


Investment in government securities 


18,000 


112 


25,821 


5,804 


4,854 








19,426 

1,146 

304 


6,513 


73,188 
28,209 


21,500 
10,839 


13,827 


31,861 


OTHER ASSETS 


4,795 


Sinking fund on local debentures. . . 










3,493 


222 


519 


117 










1,450 
366,083 




31,702 
■75,506 


11,061 
133,970 


519 
6,199 


4,912 


Equity in Ontario Hydro Systems. . . . 


53,036 


130,137 




723,011 


97,894 


881,225 


354,523 


77,406 


316,825 


LIABILITIES 


59,700 

402 

7,670 




304,000 

563 

54,077 


3,853 

407 

3,164 


31,000 
2,079 
2,544 








514 


Other 


260 


4,072 








67,772 
366,083 


260 
53,036 


353,640 

75,506 
550 


7,424 
133,970 


35,623 
6,199 


4,586 


RESERVES 

Equity in Ontario Hydro Systems. . 
Other 


130,137 
125 
















366,083 
24,239 


53,036 
6,883 


76,056 
44,351 


133,970 
49,446 


6,199 
7,000 


130,262 


CAPITAL 


29,990 






Accumulated net income invested in 
plant or held as working funds. 
Frequency standardization expense 


264,917 


37,715 


402,178 


163,683 


28,584 


151,987 
















Total capital 


289,156 


44,598 


446,529 


213,129 


35,584 


181.977 




723,011 


97,894 


881,225 


354,523 


77,406 


316,825 


B. OPERATING STATEMENTS 

REVENUE 


219,182 
829 


18.425 
49 


332,429 
5,297 


88,871 
5,203 


26,713 
246 


109 216 


Other 


1,035 






220,011 


18,474 


337,726 


94,074 


26,959 


110,251 




EXPENSE 


151,727 


13,421 


183.712 


70,303 


15,076 


73,552 


Local generation 


Operation and maintenance 


23,026 

12,226 

5,515 

7,659 


1,246 
1,063 


26,267 
54,439 
27,749 
20,792 


6,682 
8,663 
2,072 
6.903 


1,718 
2,829 
3,008 
1,997 


15,128 
8,169 


Fixed charges — interest and principal 


— depreciation 

— other 


800 


4,717 
















200,153 


16,530 


312,959 


94,623 


24,628 


101,566 




Net income or net expense 


19,858 


1,944 


24,767 


549 


2,331 


8,685 


Number of customers 


1,306 


222 


2,166 


867 


299 


1,090 



Statements A and B 
Statements for the Year Ended December 31, 1960 



173 



Almonte 
3,295 


Alvinston 
651 


Amherst- 
burg 
4,344 


Ancaster 
Twp. 
12,903 


Apple Hill 
400 


Arkona 
480 


Arnprior 
5,502 


Arthur 
1,241 


Athens 
981 


$ 
398,549 
88,051 


$ 

58,752 
17,159 


$ 
392,551 
75,269 


$ 
245,651 
34,457 


$ 

22,623 
5,137 


$ 

44,574 
9,837 


$ 
424,883 
53,072 


$ 
103,608 
23,287 


$ 

62,335 
10,360 


310,498 
2,480 


41,593 

4,560 
3,500 

877 


317,282 

4,830 

17,846 

1,128 


211,194 
13,145 


17.486 

3,150 

3,000 

719 


34,737 

4,218 
4,000 
1,513 


371,811 
42,601 


80,321 


51,975 


52,000 


10,000 
1,965 


14,000 


2,757 


140 


1,272 


4,293 


57,237 
9,478 


8,937 


23,804 
5,617 


13.285 
247 


6,869 


9.731 


43,873 
3,999 


11,965 


18,293 
















300 


346 


1,877 


250 






882 












9,478 


300 
51,940 


5,963 
287,019 


2,124 
116,278 


250 
12,544 




3,999 
195,013 


882 
77,504 




50,497 


29,585 


32,115 


427,710 


102,770 


634,068 


342,881 


37,149 


74,053 


614,696 


170,672 


102,383 






17,200 


76,635 

788 

2,001 






44,012 
3,417 
7,437 






6,722 


1,073 
91 




2,582 
70 


2,415 
683 


1,167 


1,217 


3,841 


37 


193 


7,939 

50,497 
1,895 


1,164 

51,940 
7 


21,041 

287,019 
276 


79,424 
116,278 


37 
12,544 


2,652 
29.585 


54,866 

195,013 
1,143 


3,098 
77,504 


1,360 

32,115 
206 














52,392 
72,000 


51,947 
23,529 


287,295 
51,284 


116,278 
51,611 


12,544 
5,080 


29,585 
13,113 


196,156 
81,457 


77,504 
23,913 


32,321 
12,988 


295,379 


26,130 


274,448 


95,568 


19,488 


28,703 


282,217 


66,157 


55,714 




















367,379 


49,659 


325,732 


147,179 


24,568 


41,816 


363,674 


90,070 


68,702 


427,710 


102,770 


634,068 


342,881 


37,149 


74,053 


614,696 


170,672 


102,383 


101,833 
3,376 


18,062 
150 


199,812 
2,649 


129,985 
59 


6,561 
163 


19,197 
152 


198.018 
760 


40.107 
410 


18,639 

755 


105,209 


18,212 


202,461 


130,044 


6,724 


19,349 


198,778 


40,517 


19,394 


49,277 
10,973 


10,057 


130,385 


85,433 


3,384 


14,438 


146,612 


27,931 


14,805 


8,945 
12,203 


2,115 
2,340 


11,822 
16,400 
4,606 
10,074 


11,070 
12,990 
9.117 
5,970 


513 
901 


859 
1,349 


8,321 
18,633 

6,619 
10,008 


4,979 
2,546 


1,261 

1.375 

168 


10,453 


1,760 


615 


1,241 


2,878 


1,574 




















91,851 


16,272 


173,287 


124,580 


5,413 


17,887 


190,193 


38,334 


19,183 


13,358 


1,940 


29,174 


5,464 


1,311 


1,462 


8,585 


2,183 


211 


1,085 


323 


1,451 


1,086 


117 


200 


1,751 


496 


350 



174 



Municipal Electrical Service 

Municipal Electrical Utilities Financial 



Southern Ontario System — Continued 





Aurora 
7.124 


Avonmore 
250 


Aylmer 
4,734 


Ayr 
1,035 


Baden 
882 


Bancroft 




2,497 






A. BALANCE SHEETS 

FIXED ASSETS 


$ 
528,284 
75,817 


$ 

22,673 
5,128 


$ 
319,558 
84,379 


$ 

78,977 
12,744 


$ 

67,640 
11,574 


284.792 




66,404 








452,467 
169 


17,545 
657 


235,179 
30,565 


66,233 


56,066 

4,462 

6,500 

352 


218.388 


CURRENT ASSETS 


38,873 


Investment in government securities 


10,500 
666 




4,426 


346 


8,327 


6,098 








4,595 
1,299 
4,500 


1,003 


38,892 
537 


11,166 

45 


11.314 
85 


44,971 




10,603 


Sinking fund on local debentures. . . 






459 


4,517 






1,003 












5,799 
163,545 


459 
3,757 


5,054 
263,594 


45 
68,293 


85 
114.312 


11.606 


Equity in Ontario Hydro Systems. . . 


28,519 




626,406 


22,764 


542,719 


145,737 


181,777 


303,484 


LIABILITIES 


125,000 
2,032 
13,753 


13,500 


40,500 

255 

4,126 






74,750 




2,726 
373 




858 


Other 


3,424 


150 


2,851 








140,785 

163,545 

444 


16,924 

3.757 


44.881 

263,594 
262 


3,099 
68.293 


150 
114,312 


78,459 


RESERVES 

Equity in Ontario Hydro Systems. . 
Other 


28,519 














163,989 


3,757 
500 


263,856 
48,202 


68.293 
17,503 


114.312 
5.000 


28,519 


CAPITAL 


57,750 








Accumulated net income invested in 
plant or held as working funds. 
Frequency standardization expense 


321,632 


1,583 


185,780 


56,842 


62,315 


138,756 


















321,632 


2,083 


233,982 


74,345 


67.315 


196,506 








626,406 


22,764 


542,719 


145,737 


181,777 


303,484 


B. OPERATING STATEMENTS 

REVENUE 


274,444 
9,434 


9,946 

35 


186,402 
1,322 


38,901 
519 


39,226 
188 


93 544 


Other 


93 








283,878 


9,981 


187,724 


39,420 


39,414 


93,637 






EXPENSE 


191,466 


5,369 


143,768 


27,751 


32,586 


39 797 


Local generation 


4,556 


Operation and maintenance 


25,347 
21,329 
10,020 
12,014 


426 

804 

1,261 

549 


13,900 
9,723 
4,972 
8,995 


3,784 
2,386 


2,099 
2,711 


5,518 
6 191 


Fixed charges — interest and principal 


9.649 


— depreciation 

— other 


2.012 


1,668 


7.654 
















260,176 


8,409 


181,358 


35,933 


39,064 


73,365 






Net income or net expense 


23,702 


1,572 


6,366 


3,487 


350 


20,272 


Number of customers 


2,631 


114 


1,561 


372 


281 


791 



Statements A and B 
Statements for the Year Ended December 31, 1960 



175 



Barrie 
21.271 


Barry's Bay 
1.468 


Bath 
723 


Beach ville 
820 


Beamsville 
2.387 


Beaverton 
1,159 


Beeton 
783 


Belle River 
1.847 


Belleville 
29.070 


$ 
1.742,209 
426,695 


$ 
82,765 

5,254 


$ 

61,367 
12,786 


$ 
101,904 
26,443 


$ 
136.187 
27,979 


$ 
119,365 
19,770 


$ 

67,171 
8,167 


$ 
110.413 
19,492 


$ 
1,949.490 

352,727 


1.315,514 

150 
14,063 


77.511 
15,051 


48,581 
7,245 


75,461 

19,333 

25,000 

802 


108.208 

11,488 

4,000 

582 


99.595 

4.473 


59.004 

8.438 

1.500 

927 


90,921 

738 

7,000 

361 


1.596.763 
700 


18.177 


794 


578 


280 


66.066 


32,390 
31,373 


15,845 


7,823 


45,135 


16,070 


4.753 
799 


10.865 
19 


8.099 
522 


66,766 

25,755 














100 




400 










945 


















31,473 




400 
16.241 






799 
91.099 


19 
56,435 


1.467 
59,053 


25,755 


905.633 


10,752 


186,837 


79,288 


1.190,115 


2,285,010 


104,108 


73,045 


307,433 


203,566 


196,246 


126,323 


159,540 


2,879,399 






8,000 
463 
754 










4,100 

294 

1,455 




18,112 
22,014 


1,556 

250 


483 
450 


2,613 
1,511 


642 
690 


128 
1,024 


241,233 
38,874 


40,126 

905,633 
500 


1.806 
10,752 


9.217 

16.241 
50 


933 

186,837 
193 


4.124 
79,288 


1,332 

91,099 

370 


1.152 

56,435 
87 


5,849 
59,053 


280,107 
1,190,115 












906,133 
65.366 


10,752 
7,500 


16,291 
9,500 


187,030 
5,537 


79,288 
37,500 


91,469 
12,839 


56,522 
13,610 


59,053 
16,400 


1,190.115 
174.997 


1.273,385 


84,050 


38,037 


113.933 


82,654 


90,606 


55,039 


78,238 


1,234,180 




















1.338,751 


91,550 


47,537 


119.470 


120,154 


103.445 


68,649 


94,638 


1,409,177 


2,285,010 


104,108 


73,045 


307,433 


203,566 


196,246 


126,323 


159,540 


2,879,399 



851,590 
6,699 


23,515 
87 


20,279 

1 


113,303 
1,520 


81,840 

833 


67,611 
718 


27,304 
34 


50,657 
566 


934,494 
18,222 


858,289 


23,602 


20,280 


114,823 


82,673 


68,329 


27,338 


51,223 


952,716 



532.865 


13,640 


10.990 


92.186 


53,587 


39,830 


18,380 


27.209 


693,456 


99.996 
60.707 


1.525 
3,506 


982 
2,011 

967 
1.657 


2,011 
1,481 


4,708 
7,383 


6.028 
4,945 


1.274 
1.922 


9,449 
7,446 
1.538 
2.794 


77.306 
81.517 
12 964 


48.501 


1.817 


2,886 


3,546 


2,928 


1.568 


47,052 




















742,069 


20,488 


16,607 


98,564 


69,224 


53,731 


23,144 


48,436 


912,295 


116,220 


3,114 


3,673 


16,259 


13,449 


14,598 


4,194 


2,787 


40,421 


6.961 


412 


246 


290 


855 


556 


314 


690 


9.715 



176 



Municipal Electrical Service 

Municipal Electrical Utilities Financial 



Southern Ontario System — Continued 





Blenheim 
3,045 


Bloomfield 
720 


Blyth 
743 


Bobcaygeon 
1,197 


Bolton 
1,921 


Bothwell 




804 






A. BALANCE SHEETS 

FIXED ASSETS 


$ 
301,233 
45,131 


$ 

58.990 
18,410 


$ 

66,245 
10,113 


$ 
211,932 
43,768 


$ 
153.697 
22,790 


$ 
59,231 




17,101 








256,102 
3,119 


40,580 

1,805 

8,992 

138 


56,132 

12,897 

2,000 

295 


168,164 
6,645 


130,907 
4,227 


42,130 


CURRENT ASSETS 


1,754 


Investment in government securities 
Accounts receivable 


5,952 


1,552 


792 


2,130 


666 




4,671 

1,673 

230 


10,935 
465 


15,192 
58 


7,437 
4,614 


6,357 
371 


8,372 


OTHER ASSETS 


28 


Sinking fund on local debentures. . . 




1,050 




5,565 


1,720 












1,903 
163,182 


1,515 
34,900 


58 
52,147 


10,179 
25,476 


2,091 
76,966 


28 


Equity in Ontario Hydro Systems .... 


61,001 




425,858 


87,930 


123,529 


211,256 


216,321 


111,531 


LIABILITIES 


51,111 

186 

8,001 






84,000 

423 

7,055 


49,681 
11,194 
3,338 






502 
569 


79 
237 


228 


Other 


150 








59,298 

163,182 
183 


1,071 
34,900 


316 
52,147 


91,478 
25,476 


64,213 

76,966 
216 


378 


RESERVES 

Equity in Ontario Hydro Systems. . 
Other 


61,001 














163,365 
46,889 


34,900 
9,797 


52,147 
16,033 


25,476 
15,283 


77,182 
17,524 


61,001 


CAPITAL 


5,534 






Accumulated net income invested in 
plant or held as working funds. 
Frequency standardization expense 


156,306 


42,162 


55,033 


79,019 


57,402 


44,618 
















Total capital 


203,195 


51,959 


71,066 


94,302 


74,926 


50,152 




425,858 


87,930 


123,529 


211,256 


216,321 


111,531 



B. OPERATING STATEMENTS 

REVENUE 


98,533 
2,739 


16,927 
675 


35,419 
104 


53,905 
359 


71,012 
951 


23,977 


Other 


738 






Total revenue 


101,272 


17,602 


35,523 


54,264 


71,963 


24,715 




EXPENSE 


55,499 


14,440 


27,054 


26,964 


45,358 


14 133 


Local generation 




Operation and maintenance 


12,062 

14,187 

9,844 

7,379 


1,385 
2,183 


2,708 
2,018 


4,329 
6,531 
6,964 
6,040 


4,872 
8,179 
4,950 
3,628 


2,975 
2,718 


Fixed charges — interest and principal 


— depreciation 

— other 


1,104 


1,641 


1,719 
















Total expense 


98,971 


19,112 


33,421 


50,828 


66,987 


21,545 


Net Income or net expense 


2,301 


1,510 


2,102 


3,436 


4,976 


3,170 


Number of customers 


1,125 


313 


326 


711 


654 


319 



Statements A and B 
Statements for the Year Ended December 31, 1960 



177 



Bowman- 
ville 
7,308 


Bracebridge 
2,906 


Bradford 
2,395 


Braeside 
563 


Brampton 
17,385 


Brantford 
53,616 


Brantford 
Twp. 
7,473 


Brechin 
259 


Bridgeport 
1,674 


$ 
653,416 
188,836 


$ 
845,555 
194,560 


$ 
234,147 
31,173 


% 

30,033 
1,715 


$ 
1,613,065 
125,623 


$ 
4,745,111 
1,082,147 


$ 
986,712 
241,991 


% 

20,424 
3,215 


$ 

87,899 
19,941 


464,580 

20,677 
119,217 


650,995 
19,031 


202,974 

14,245 
8,000 
4,353 


28,318 
15,992 


1,487,442 

100 
1,500 

22,275 


3,662,964 

3,261 
32,000 
66,620 


744,721 

17,317 
45,000 
13,808 


17,209 

2,551 

7,000 

235 


67,958 

2,756 
5,000 


5,251 


1,888 


6,240 


1,000 


145,145 
14,162 


20.919 
16,150 


* 26,598 
10,212 


22,232 


23,875 
26,491 


101,881 
85,844 


76,125 
23,144 


9,786 


8,756 

22 












664 


371 




992 


1,583 


4,276 


300 


138 








14,162 


16,814 
1,861 


10,583 
102,659 




27,483 
785,063 


87,427 
4,403,553 


27,420 
202,998 


300 
24,004 


160 


441,786 


19,119 


47,011 


1,065,673 


690,589 


342,814 


69,669 


2,323,863 


8,255,825 


1,051,264 


51,299 


123,885 




248,961 
325 
885 




1,602 


491,635 
137,952 
26,478 


543,880 
23,344 
72,213 


486,329 

2,339 

19,314 




16,709 


841 




2,165 
140 




3,464 


2,368 


215 


1,863 


4,305 

441,786 

475 


250,171 
1,861 


2,368 

102,659 
95 


1,817 
19,119 


656,065 

785,063 
540 


639,437 

4,403,553 
1,743 


507,982 

202,998 

328 


2,305 

24,004 
50 


18,572 
47,011 










442,261 
71,000 


1,861 
256,839 


102,754 
23,351 


19,119 
4,398 


785,603 
139,311 


4,405,296 
900,803 


203,326 
78,784 


24,054 
2,664 


47,011 
14,818 


548,107 


181,718 


214,341 


44,335 


742,884 


2,315,623 

5,334 


261,172 


22,276 


43,484 


















619,107 


438,557 


237,692 


48,733 


882,195 


3,211,092 


339,956 


24,940 


58,302 


1,065,673 


690,589 


342,814 


69,669 


2.323,863 


8,255,825 


1,051,264 


51,299 


123,885 



265,136 
10,772 


127,131 
1,992 


101,096 
537 


67,093 

72 


643,578 
7,919 


2,185,040 
3,956 


384,247 

3,748 


7,551 
212 


45,511 
416 


275,908 


129,123 


101,633 


67,165 


651,497 


2,188,996 


387,995 


7,763 


45,927 


196,889 


1,855 
31,404 
18,317 
12,107 
29,42 7 
17,582 


63,610 


51,683 


398,552 


1,619,151 


210,373 


3,724 


32,631 


28,258 
19,686 


14,006 
10,416 


900 

1,083 

451 

643 


41,833 
42,662 
44,712 
32,078 


125,150 
88,491 
65,345 

129,853 


35,092 
27,599 
43,016 
27,363 


664 
760 


2,864 
5,615 
1,510 


19,040 


5.207 


494 


2,405 




















263,873 


110,692 


93,239 


54,760 


559,837 


2,027,990 


343,443 


5,642 


45,025 


12,035 


18,431 


8,394 


12,405 


91,660 


161,006 


44,552 


2,121 


902 


2,446 


1,133 


836 


161 


5,392 


17,009 


2,195 


99 


460 



178 



Municipal Electrical Service 

Municipal Electrical Utilities Financial 



Southern Ontario System — Continued 





Brigden 
491 


Brighton 
2,345 


Brockville 
17,124 


Brussels 
830 


Burford 
1.029 


Burgess- 




ville 
245 






A. BALANCE SHEETS 

FIXED ASSETS 


$ 

46,805 
10,366 


$ 
220,105 
16,761 


$ 
1,651,260 
385,918 


$ 
71,939 

7,030 


$ 

75,398 
20,594 


$ 
22,658 




6,382 








36,439 

7,884 

1,975 

663 


203,344 
3,007 


1,265,342 

20,756 
12,000 
29,524 


64,909 
1,703 


54,804 

12,127 

3,500 

979 


16,276 


CURRENT ASSETS 

Cash on hand and in bank 

Investment in government securities 


2,467 
1,500 


1,543 


733 


168 








10,522 

28 
13 


4,550 
9,576 


62,280 
19,169 


2,436 
103 


16,606 
122 


4,135 


OTHER ASSETS 




Sinking fund on local debentures. . . 




1,980 


2,743 


















41 
41,404 


11,556 
87,745 


21.912 
1,032,720 


103 
62,458 


122 
67,043 




Equity in Ontario Hydro Systems. . . . 


21,881 




88,406 


307,195 


2,382,254 


129,906 


138,575 


42,292 


LIABILITIES 




39,000 
4,605 
3,135 


203,500 

126,199 

17,694 




10,919 






4,203 
191 


414 
307 


739 


Other 


1,256 










4,394 

41,404 
40 


46.740 

87.745 


347,393 

1,032,720 
174 


721 
62,458 


12,175 
67,043 


739 


RESERVES 

Equity in Ontario Hydro Systems. . 
Other 


21.881 














41,444 
8,000 


87,745 
26,000 


1,032,894 
188,770 


62,458 
21,000 


67,043 
9,935 


21,881 


CAPITAL 


3,500 






Accumulated net income invested in 
plant or held as working funds. 
Frequency standardization expense 


34,568 


146,710 


813,197 


45,727 


49,422 


16,172 


















42,568 


172,710 


1,001,967 


66,727 


59,357 


19,672 








88,406 


307,195 


2,382,254 


129,906 


138,575 


42,292 



B. OPERATING STATEMENTS 

REVENUE 


15,470 
283 


74,393 
1,011 


717,827 
16,439 


36,793 
160 


46.606 
261 


10 737 


Other 


135 






Total revenue 


15,753 


75,404 


734,266 


36,953 


46,867 


10,872 






EXPENSE 


9,891 


47,506 


486,273 


26,444 


30,090 


7,719 


Local generation 


Operation and maintenance 


1.288 
1.432 


8,479 
9,545 
3.374 
4,387 


76,268 
64,424 
18,952 
41,485 


1,929 
2,399 


2,842 
2,918 
1,215 
2,163 


211 
479 


Fixed charges — interest and principal 




— depreciation 

— other 


1,310 


1,684 


697 


















13,921 


73,291 


687,402 


32,456 


39,228 


9,106 




Net income or net expense 


1,832 


2,113 


46,864 


4,497 


7,639 


1,766 


Number of customers 


215 


981 


5,879 


385 


427 


100 



Statements A and B 
Statements for the Year Ended December 31, 1960 



179 



Burk's Falls 
884 


Burlington 
44,709 


Caledonia 
2.265 


Campbell- 
ford 
3,373 


Campbell- 
ville 
364 


Cannington 
1 .059 


Cardinal 
1,972 


Carleton 
Place 
4,688 


Casselman 
1,301 


$ 

79,164 

12,887 


$ 
3,416.334 
519,412 


$ 
150,983 
26,998 


$ 
674,628 
129,578 


17,026 
4,596 


$ 

71,537 
17,471 


$ 

73,890 
12,746 


$ 
264,684 
51,166 


$ 

89,749 
8,520 


66,277 
3 094 


2.896,922 

131,568 
37,500 
65,640 


123,985 
5,200 


545,050 
150 


12,430 

3,683 

2,398 

112 


54,066 

12,363 

6,000 

799 


61,144 

9,670 

1,500 

473 


213,518 


81,229 
4,558 


4 900 


15.000 
5,168 


14,000 


1,412 


4,487 


8,624 


19 


9,406 
291 


234,708 
42,531 


9,687 
423 


8,774 
11,862 


6,193 


19,162 

58 


11,643 


20,168 
6.126 


18,577 












93,936 


121 


1,579 


12 




500 


100 


4,838 








291 
15.200 


136,467 

582,588 


544 
99,426 


13,441 
830 


12 
14,083 


58 
67,410 


500 
58,024 


6,226 
361,353 


4,838 
14,292 


91,174 


3,850,685 


233,642 


568,095 


32,718 


140,696 


131,311 


601,265 


118,936 


11.162 


1,966,221 

4,503 

130,375 


2,500 

608 

2,402 


63,000 

68,631 

5,059 








13,680 
6,280 
3,496 


48,500 


323 


21 


1,107 
365 




14 


121 


180 


55 








11,606 
15,200 


2,101,099 

582,588 


5,510 
99,426 


136,690 

830 
350 


21 

14,083 
8 


1,472 

67,410 
35 


180 
58,024 


23,456 

361,353 
166 


48,569 
14,292 


1 








15.200 
23,838 


582,588 
284,207 


99,426 
13,024 


1,180 
2,000 


14,091 
5,448 


67,445 
14,533 


58,024 
11,014 


361,519 
59,617 


14,292 
21,500 


40,530 


882,791 


115,682 


428.225 


13,158 


57,246 


62,093 


156,673 


34,575 


















64,368 


1,166,998 


128,706 


430.225 


18,606 


71,779 


73,107 


216,290 


56,075 


91,174 


3,850,685 


233,642 


568,095 


32,718 


140,696 


131,311 


601,265 


118,936 


33,612 
684 


1,927,526 
6,521 


63,545 
142 


101.995 
2,495 


9,031 
94 


37,740 
306 


44,633 

198 


176,871 
1,068 


39,020 

725 


34,296 


1,934,047 


63,687 


104,490 


9,125 


38,046 


44,831 


177,939 


39,745 


20,031 


1.088,284 


38,744 


29,509 
25,454 
12,768 
25,720 
5,488 
7,644 


6,597 


22,312 


34,628 


118,381 


24,156 


3,377 
3,066 
3,039 


130,358 

128,546 

180,893 

79,130 


7,124 

7,922 

643 

3,770 


417 
547 


1,629 
2,827 


3,443 
3,503 


17,519 

25,326 

1.580 

6,829 


2,178 
3.529 

5.575 


1.874 


498 


2,047 


1,879 


1.985 




















31,387 


1,607,211 


58,203 


106,583 


8,059 


28,815 


43,453 


169,635 


37,423 


2,909 


326,836 


5,484 


2,093 


1,066 


9,231 


1,378 


8,304 


2,322 


341 


13,547 


788 


1.346 


90 


450 


663 


1,712 


379 



180 



Municipal Electrical Service 

Municipal Electrical Utilities Financial 



Southern Ontario System— Continued 





Cayuga 
920 


Chalk 
River 
1,052 


Chatham 
29,271 


Chats- 
worth 
399 


Chesley 
1,635 






ville 
1,248 






A. BALANCE SHEETS 

FIXED ASSETS 


$ 

91,616 
16,969 


$ 

66,582 
12,942 


$ 
2,892,409 
618,896 


$ 

29,934 
8,711 


$ 
111,525 
35,511 


80,424 




15,500 








74,647 

6,000 
718 


53,640 
8,856 


2,273,513 

54,760 
140,000 
170,273 


21,223 

7,305 

6,000 

398 


76,014 

13,111 

17,000 

410 


64,924 


CURRENT ASSETS 

Cash on hand and in bank 

Investment in government securities 


16,428 
6,000 


3,546 


3,481 








6,718 
292 


12,402 


365,033 
88,456 


13,703 


30,521 
974 


25 909 


OTHER ASSETS 




Sinking fund on local debentures . . . 








2,633 


44,630 




















292 
44,477 


2,633 
10,335 


133,086 
1,824,185 




974 
151.312 




Equity in Ontario Hydro Systems. . • . 


24,792 


114,827 




126,134 


79,010 


4,595,817 


59,718 


258,821 


205,660 


LIABILITIES 




48,500 


684,684 
94,053 
36,446 










645 
1,260 


64 

148 


476 


200 


Other 


566 


154 










1,905 

44,477 
62 


49,066 
10,335 


815,183 

1,824,185 
72,855 


212 
24,792 


476 
151,312 


354 


RESERVES 

Equity in Ontario Hydro Systems. . 
Other 


114,827 














44,539 
20,000 


10,335 
6,500 


1,897,040 
835,316 


24,792 
5,014 


151,312 
24,410 


114,827 
5,889 


CAPITAL 


Local sinking fund 


Accumulated net income invested in 
plant or held as working funds. 

Frequency standardization expense 
charged this year 


59,690 


13,109 


1,048,278 


29,700 


82,623 


84.590 


















79,690 


19,609 


1,883,594 


34,714 


107,033 


90,479 






126,134 


79,010 


4,595,817 


59,718 


258,821 


205,660 



B. OPERATING STATEMENTS 

REVENUE 


28,359 
161 


23,236 

357 


1,459,215 
15,555 


14,558 
300 


59,545 
917 


67 432 


Other 


422 






Total revenue 


28,520 


23,593 


1,474,770 


14,858 


60,462 


67,854 




EXPENSE 


17,330 


16,211 


736,355 


9,925 


42,746 




Local generation 




Operation and maintenance 


4,313 
5.305 


880 
1,584 
4,778 
1,655 


306,427 

182,585 

90,616 

76,049 


1,051 
1,149 


5,140 
5,337 


3,399 
5,161 


Fixed charges — interest and principal 


— depreciation 

— other 


2,368 


894 


3,485 


2,098 


















29,316 


25,108 


1,392,032 


13,019 


56,708 


60,827 




Net income or net expense 


796 


1,515 


82,738 


1,839 


3,754 


7,027 


Number of customers 


371 


290 


9,509 


165 


717 


457 



Statements A and B 
Statements for the Year Ended December 31, 1960 



181 



Chippawa 
3,027 


Clifford 
557 


Clinton 
3,107 


Cobden 
915 


Cobourg 
9,445 


Col borne 
1,337 


Coldwater 

752 


Collingwood 
8,505 


Comber 
580 


$ 
196,438 
33,930 


$ 

43,974 
6,704 


$ 
298,431 
46,117 


$ 

68,858 
8,082 


$ 
910,672 
192,775 


% 
92,323 

10,578 


$ 

56,686 
11,654 


$ 
540,680 
96,715 


$ 

54.097 
12,638 


162,508 
24,684 


37,270 

7,811 

3,000 

92 


252,314 
1,803 


60,776 

1,967 

18,000 

248 


717,897 

61,417 

10,000 
31,663 


81,745 
130 


45,032 

14,632 

12,500 

1.466 


443,965 

44,160 

33,331 

5,815 


41.459 
4.355 


6.066 


4,583 


7.565 


328 


30.750 
165 


10,903 
17 


6,386 
5,205 


20.215 


103,080 
18,334 


7,695 
14,028 


28,598 


83,306 
19,138 


4,683 
12 










1,097 




310 


681 


435 


11 


57 


1,406 


921 








1,262 
80,901 


17 
35,779 


5,515 
211,780 


681 
27,555 


18,769 
475,171 


14.039 
47,148 


57 
53,396 


20,544 
588,114 


933 
61,410 


275,421 


83,969 


475,995 


109,227 


1,314,917 


150,627 


127,083 


1,135,929 


108,485 


63,000 


5,854 


55,100 
1,161 
8,530 












2,269 


4,715 


8,724 
238 




10,840 
1,751 




356 
7,139 


590 


2,652 


336 


12.839 


210 


609 


70,367 

80,901 
64 


6,190 
35,779 


64,791 

211,780 
18 


8,962 
27,555 


12,839 
475,171 


12,591 
47,148 


210 

53,396 
137 


7,495 

588,114 
300 


3,468 

61,410 
15 














80,965 
15,350 


35,779 
9,075 


211,798 
66,573 


27,555 
4,949 


475,171 
105,993 


47,148 
12,195 


53,533 
6,868 


588,414 
38,183 


61,425 
10,431 


108,739 


32,925 


132,833 


67,761 


720.914 


78,693 


66,472 


501,837 


33,161 




















124,089 


42,000 


199,406 


72,710 


826.907 


90,888 


73,340 


540,020 


43,592 


275,421 


83,969 


475,995 


109,227 


1,314,917 


150,627 


127,083 


1,135,929 


108,485 


83,124 
270 


20,453 
637 


126,843 
1,573 


21,732 
750 


469,764 
2,339 


50,867 
2,500 


30,221 
583 


318,254 
4,334 


20,315 

5 


83,394 


21,090 


128,416 


22,482 


472,103 


53,367 


30,804 


322,588 


20,320 


49,497 


15,372 


86,291 


19,594 


311,486 


32.669 


18,879 


197.142 


12,180 


8,544 
6,858 
4,620 


846 
1,476 

567 
1,056 


14,820 
9,258 
6,743 
7,201 


2,203 
1,964 


25,378 
37,323 


4,035 

6,709 

381 

2.092 


2,567 
2,212 


23,100 
21,947 


1,746 

2,155 

419 


4,881 


1,520 


23,592 


1,545 


13.517 


1,490 




















74,400 


19,317 


124,313 


25,281 


397,779 


45,886 


25,203 


255,706 


17,990 


8,994 


1,773 


4,103 


2,799 


74,324 


7,481 


5,601 


66,882 


2,330 


1,035 


227 


1,232 


403 


3,387 


572 


270 


3.115 


234 



182 



Municipal Electrical Service 

Municipal Electrical Utilities Financial 



Southern Ontario System — Continued 





Cookstown 
650 


Cottam 
649 


Courtright 
548 


Creemore 
882 


Dashwood 
433 






5,130 






A. B\LANCE SHEETS 

FIXED ASSETS 

Plant and facilities at cost 


$ 

50,511 
9,020 


$ 

52,586 
13,046 


$ 

28,193 
4,946 


$ 
53,293 

5,555 


$ 

27,429 
4,807 


$ 
559,165 
101 967 








41,491 

5,453 

5,000 

763 


39,540 

4,818 

3,000 

13 


23,247 

554 

4,000 

206 


47.738 

1,267 

5,000 

793 


22,622 
3,702 


457 198 


CURRENT ASSETS 


63,570 






88 


2 734 








11,216 


7,831 
95 


4,760 
32 


7,060 


3,790 


66 304 




6,235 














202 




364 




8,259 
















297 
23,121 


32 
22,351 


364 
49,556 




14,494 


Equity in Ontario Hydro Systems .... 


27,443 


35,657 


24,643 




80,150 


70,789 


50,390 


104,718 


62,069 


562,639 


LIABILITIES 




2,000 

1,415 

861 








219,000 




958 
670 


5,307 
467 


12 
570 


97 


938 


Other 


15,590 










1.628 

27,443 
50 


4,276 
23,121 


5,774 

22,351 
80 


582 

49,556 

50 


97 

35,657 
7 


235 528 


RESERVES 
Equity in Ontario Hydro Systems. . 
Other 


24,643 










27,493 
12,001 


23,121 
12,000 


22,431 
8,138 


49,606 

2.824 


35,664 

3.400 


24,643 


CAPITAL 


12 000 


Local sinking fund 




Accumulated net income invested in 

plant or held as working funds. 

Frequency standardization expense 


39,028 


31,392 


14,047 


51,706 


22,908 


290,468 


















51,029 


43,392 


22,185 


54,530 


26,308 


302,468 








80,150 


70,789 


50,390 


104,718 


62,069 


562,639 



B. OPERATING STATEMENTS 

REVENUE 


18,382 
233 


16,533 
92 


8,665 
236 


26,447 

455 


16,908 
8 


200,087 


Other 


2 435 








18,615 


16,625 


8,901 


26,902 


16,916 


202,522 






EXPENSE 


12,979 


9,936 


6,947 


17,753 


12,192 


109,262 


Local generation 


Operation and maintenance 


1,722 
1,310 

1,289 


2,262 

1,920 

601 

1,499 


2,563 

1,003 

225 

715 


1,621 

1,770 

306 

1,255 


1,548 
1,542 


13,461 
14,594 
18,008 


Fixed charges — interest and principal 


— depreciation 

— other 


712 


14,006 


















17,300 


16,218 


11,453 


22,705 


15,994 


169,331 




Net income or net expense 


1,315 


407 


2,552 


4,197 


922 


33,191 


Number of customers 


250 


244 


191 


363 


183 


1,383 



Statements A and B 
Statements for the Year Ended December 31, 1960 



183 



Delaware 

452 


Delhi 
3,434 


1 
Deseronto 

1,770 


Dorchester 
937 


Drayton 
620 


Dresden 
2,311 


Drum bo 
399 


Dublin 
271 


Dundalk 
875 


$ 

27.853 
7,790 


$ 
291,511 
56,763 


$ 
121,071 
27,932 


$ 

56,357 
13,596 


$ 

54.380 
9,745 


$ 
185,374 
27,434 


29,716 

10,064 


$ 
34,602 

7,735 


$ 

59,972 
11,870 


20,063 
638 


234,748 

13.297 
10.000 

2.557 


93.139 

2.758 
16,000 
3,201 


42,761 

2,943 

1,500 

538 


44,635 

3,497 

6,000 

563 


157,940 

4,628 

21,000 

3,606 


19,652 

1,266 
5,500 
1,863 


26,867 

642 

600 

13 


48,102 

7,579 
6,500 


882 


2,155 


1,520 


25.854 
17,510 


21.959 
10,202 


4,981 


10,060 
142 


29,234 
11,139 


8.629 


1,255 


16,234 












90 


88 








760 




1,500 
















90 


17,598 
107,167 


10,202 
60,389 




142 
49,306 


11,899 
140,079 




1,500 
22,307 




19.272 


34,355 


28.908 


58,508 


40,945 


385,367 


185,689 


82,097 


104,143 


339,152 


57,189 


51,929 


122,844 








2,261 
334 
419 




19,967 

261 

2,694 








241 
20 


3,835 
4.792 


406 
1,221 


231 
325 


88 
115 


1,219 
90 


1,664 
270 


261 

19,272 
30 


8,627 

107,167 

75 


1,627 
60,389 


3,014 
34,355 


556 
49,306 


22.922 

140.079 
546 


203 
28.908 


1,309 
22.307 


1,934 
58,508 
















19,302 
4,000 


107,242 
85,000 


60,389 
15,000 


34,355 
5.039 


49,306 
9,500 


140.625 
31,456 


28,908 
4,500 


22,307 
6,200 


58.508 

5,727 


17,382 


184,498 


108,673 


39.689 


44,781 


144,149 


23.578 


22,113 


56,675 




















21,382 


269,498 


123,673 


44.728 


54,281 


175,605 


28.078 


28,313 


62,402 


40,945 


385,367 


185,689 


82,097 


104,143 


339,152 


57,189 


51,929 


122,844 


14,681 
119 


143,657 
2,773 


52,699 
1,091 


21.142 
243 


22.993 
276 


99.226 
4.450 


12.770 
376 


11,936 

27 


32,899 
240 


14,800 


146,430 


53,790 


21,385 


23,269 


103,676 


13,146 


11,963 


33,139 


9,905 


92,160 


37,084 


14.401 


15,266 


62,042 


10,055 


9,022 


22,170 


412 
1,231 


16,093 

12,250 

2,111 

7,375 


5,678 
5,504 


858 
1.685 

240 
1,582 


2,099 
1,938 


16,479 
12,484 
3,942 
4,338 


755 
1,154 


935 
995 


3,662 

1,800 


804 


3,322 


1,385 


586 


930 


1,555 




















12,352 


129,989 


51,588 


18,766 


20,688 


99,285 


12,550 


11,882 


29,187 


2,448 


16,441 


2,202 


2,619 


2,581 


4,391 


596 


81 


3,952 


136 


1.364 


638 


327 


263 


895 


174 


111 


426 



184 



Municipal Electrical Service 

Municipal Electrical Utilities Financial 



Southern Ontario System — Continued 





Dundas 
12.790 


Dunnville 
5.261 


Durham 
2,084 


Dutton 

777 


East York 
Twp. 
68,209 






1,454 






A. BALANCE SHEETS 

FIXED ASSETS 


$ 
1.093.411 
167,943 


S 
404.057 
66,961 


$ 
151,353 
17,588 


$ 

44,937 
13,947 


$ 
4,031,343 
591,572 


$ 
163,973 




40,309 








925.468 

801 
9,000 
2.487 


337.096 
28,580 


133,765 

17.672 

4.000 

934 


30,990 

4,683 

5,500 

743 


3,439,771 

64,522 
350.000 
135,706 


123,664 


CURRENT ASSETS 


10,484 




10,000 




35.670 


452 








12,288 
9,109 
1,424 


64,250 
38.312 


22.606 
2,401 


10,926 
13 


550,228 

29,096 
93,738 

7,218 


20 936 


OTHER ASSETS 


2,420 








828 


132 




1 993 










10.533 
608,631 


39,140 
322,493 


2,533 
133.087 


13 
71,736 


130,052 
2,164,462 


4,413 


Equity in Ontario Hydro Systems .... 


9,356 




1,556,920 


762,979 


291,991 


113,665 


6,284,513 


158,369 


LIABILITIES 


403,000 
12,206 
27.667 


52,100 
12.965 
8.230 






602,017 

156,835 

26,660 


41,449 




440 
1,129 


866 
397 




Other 










442.873 
608,631 


73,295 

322,493 
810 


1,569 
133,087 


1,263 
71,736 


785,512 

, 2.164.462 
8,266 


41 449 


RESERVES 

Equity in Ontario Hydro Systems. . 
Other 


9,356 














608,631 
86,969 


323,303 
88.400 


133,087 
25.324 


71,736 
8,407 


2,172,728 

675,022 
93,738 

2,557,513 


9 356 


CAPITAL 


58 551 


Local sinking fund 




Accumulated net income invested in 
plant or held as working funds. 

Frequency standardization expense 
charged this year 


418,447 


277,981 


132,011 


32,259 


49,013 


















505,416 


366,381 


157,335 


40.666 


3,326.273 


107 564 








1,556,920 


762,979 


291,991 


113,665 


6,284,513 


158,369 


B. OPERATING STATEMENTS 

REVENUE 

Sales of electric energy 


460,878 
1,715 


231,456 

1,073 


91,170 
818 


23,140 

247 


1,878,757 
55,181 


57,101 


Other 


582 








462,593 


232,529 


91,988 


23,387 


1,933,938 


57,683 






EXPENSE 


297,500 


130,292 


58,409 


17,485 


1,302,275 


20 774 


Local generation 


11,887 


Operation and maintenance 


35,325 
25,204 
35,407 
23.603 


19,763 
11,987 
5,358 
9.696 


12,406 

7,101 


1,742 
1,638 


147,092 

169,440 

76.583 

95.389 


3,638 

5 737 


Fixed charges — interest and principal 


7.035 


— depreciation 

— other 


3,400 


826 


4,458 


















417,039 


177,096 


81,316 


21,691 


1,790,779 


53,529 




Net income or net expense 


45,554 


55,433 


10,672 


1,696 


143,159 


4,154 


Number of customers 


4,010 


1,913 


822 


343 


22.769 


567 



Statements A and B 
Statements for the Year Ended December 31, 1960 



185 



Elmira 
3.222 


Elm vale 
942 


Elmwood 
450 


Elora 
1,509 


Embro 

547 


Erieau 

477 


Erie Beach 
130 


Erin 
1,010 


Essex 
3,416 


$ 
325,025 
76,500 


$ 
67,259 

17,774 


$ 

24,518 
6,230 


$ 
106,632 
31,923 


45,286 
15,731 


$ 

82,762 
12,967 


$ 
23,345 

2,457 


$ 

55,944 
6,142 


$ 
263,544 
61,933 


248,525 
22,708 


49,485 

7,519 

11,922 

678 


18,288 

754 

8,000 

78 


74,709 

11,010 

3,690 

449 


29,555 

7,686 

6,000 

504 


69,795 

4,564 

7,880 

683 


20,888 


49,802 

3,871 

5,100 

735 


201,611 
6,191 








810 


103 


2,056 


23.518 
706 


20,119 
2,542 


8,832 


15,149 
172 


14,190 


13,127 
30 


103 


9,706 


8,247 
4,416 














600 


567 






1,552 


517 


258 


1,427 












1,306 


3,109 
59.807 




172 
139,196 




1,582 
38,481 


517 
7,015 


258 
15,650 


5,843 


343,882 


20,572 


45,541 


155,213 


617,231 


132,520 


47,692 


229,226 


89,286 


122,985 


28,523 


75,416 


370,914 








5,100 

125 

1,398 




11,171 


3,259 

1,412 

232 


4,350 
154 

757 


20,400 


87 


472 
600 


1.181 
45 


116 

87 


66 


2.381 


1,055 


2,178 


2.468 
343.882 


1,072 

59,807 
50 


1,226 
20,572 


6,623 
139,196 


203 

45,541 
33 


12,226 

38,481 
22 


4,903 

7,015 
81 


5,261 

15,650 
60 


22,644 

155,213 
1,111 










343.882 
37.169 


59,857 
6,544 


20,572 
6,106 


139,196 
14,762 


45,574 
7,500 


38.503 
10,713 


7,096 
5,041 


15,710 
10,150 


156,324 
31,110 


233,712 


65,047 


19,788 


68,645 


36,009 


61,543 


11,483 


44,295 


160,836 




















270,881 


71,591 


25,894 


83,407 


43,509 


72,256 


16,524 


54,445 


191,946 


617,231 


132,520 


47,692 


229,226 


89,286 


122,985 


28,523 


75,416 


370,914 



191,073 

3,030 


31.223 
613 


7,895 
413 


53,697 
70 


22.252 

552 


28,310 
720 


5,438 
4 


32,334 
404 


104,665 
930 


194,103 


31,836 


8,308 


53,767 


22,804 


29,030 


5,442 


32,738 


105,595 


148,744 


20,172 


6,474 


34,608 


15,137 


15,838 


2,514 


21,678 


58,911 


13,351 
13.251 


2.520 
3,255 


828 
1,114 


6,778 

3,835 

635 

3.116 


1,029 
2,037 


4,698 
2,811 
1,895 
2,029 


840 

1,042 

684 

542 


3,395 

3,932 

890 

1.266 


15,886 
13,732 
4,932 


9,065 


1,968 


727 


1,436 


7,134 




















184,411 


27,915 


9,143 


48,972 


19,639 


27,271 


5,622 


31,161 


100,595 


9,692 


3,921 


835 


4,795 


3,165 


1,759 


180 


1,577 


5,000 


1.143 


406 


138 


530 


232 


350 


139 


405 


1,205 



186 



Municipal Electrical Service 

Municipal Electrical Utilities Financial 



Southern Ontario System — Continued 





Etobicoke 

Twp. 

144,777 


Exeter 
2,977 


Fergus 
3,894 


Finch 
403 


Flesherton 
495 


Fonthill 




2,321 






A. BALANCE SHEETS 

FIXED ASSETS 


$ 

14,614,671 

1,511,006 


$ 
245,184 
56,013 


$ 
302,261 
49,723 


$ 
39,973 

8,843 


$ 

34,744 
10,732 


155,524 




23,966 








13,103,665 

768,234 

37,000 

310,464 


189,171 

250 
5,000 
2,495 


252,538 

10,228 
15,769 
5,087 


31,130 

3,142 

10,000 

216 


24,012 

1,452 

20,000 

164 


131,558 


CURRENT ASSETS 


3,058 








1,553 








1,115,698 

241,954 
579,864 

280,874 


7,745 
1,414 


31,084 

508 


13,358 


21,616 
30 


4,611 


OTHER ASSETS 


92 










8 


30 






1,175 












1,102.692 
3,297,426 


1,422 
205,774 


538 
320,562 




30 
28,838 


1,267 


Equity in Ontario Hydro Systems. . . . 


23,222 


57,496 




18,619,481 


404,112 


604,722 


67,710 


74,496 


194,932 


LIABILITIES 


8,025,302 
124,367 
346,138 




23,000 
1,690 
3,732 






15,550 




2,169 
2,380 


4,264 
263 


351 
148 


1 003 


Other. 


9,110 








8,495,807 

3,297,426 
10,048 


4,549 

205,774 
14 


28,422 

320,562 
338 


4,527 
23,222 


499 

28,838 


25,663 


RESERVES 

Equity in Ontario Hydro Systems. . 
Other 


57,496 










Total reserves 


3,307,474 

1,491,795 
579,864 

4,744,541 


205,788 
20,000 


320,900 
51,961 


23,222 
7.000 


28,838 
5,831 


57,496 


CAPITAL 

Debentures redeemed 


45,798 


Local sinking fund 




Accumulated net income invested in 
plant or held as working funds. 

Frequency standardization expense 
charged this year 


173,775 


203,439 


32,961 


39,328 


65,975 
















Total capital 


6,816,200 


193,775 


255,400 


39.961 


45,159 


111 773 








18,619,481 


404,112 


604,722 


67,710 


74,496 


194,932 



B. OPERATING STATEMENTS 

REVENUE 

Sales of electric energy. ..... 


6,736.647 
44,076 


132,397 
2,222 


196,136 
507 


12,689 
395 


15,617 
910 


69 525 


Other 


1,643 




Total revenue . . 


6,780,723 


134,619 


196,643 


13,084 


16,527 


71,168 






EXPENSE 

Power purchased 


4,202,618 


92,454 


141,391 


10,163 


13,378 


44 087 


Local generation 




Operation and maintenance 

Administration 


431,256 
362,262 
709,165 
312,618 


10,112 
15,264 


17,446 

11,399 

2,987 

7,363 


1,267 
1,540 


1,221 
1,304 


3,560 
5,508 
4,713 


Fixed charges — interest and principal 


— depreciation 

— other 


6,509 


1,095 


1,083 


3,853 


















6,017,919 


124,339 


180,586 


14,065 


16,986 


61,721 




Net income or ner expense 


762,804 


10,280 


16,057 


981 


459 


9,447 


Number of customers 


49,238 


1,208 


1,336 


176 


251 


777 



Statements A and B 
Statements for the Year Ended December 31, 1960 



187 



Forest 
2,065 


Forest Hill 
20,225 


Frankford 
1.576 


Gait 
26,945 


Georgetown 
10,015 


Glencoe 
1,144 


Goderich 
6,232 


Grand Bend 
906 


Grand 

Valley 

641 


$ 
129,293 
41,376 


1,732,833 
471,891 


$ 

94,266 
10,756 


$ 
2,756,500 
838,923 


$ 
882,463 
106,430 


$ 
108,039 
30,441 


$ 
633,061 
147,067 


146,489 
30,687 


$ 

50.277 
15,769 


87,917 

9,930 
47,768 


1,260.942 

100,336 

197,438 

14,454 


83,510 
7,405 


1,917,577 

51,210 
90,000 
16,778 


776,033 

11,024 
4,000 
3,240 


77,598 

3,469 

10,000 

2,699 


485,994 

54,138 

89,952 

6.495 


115,802 
542 


34.508 

9.168 
5 500 


1,793 


1,389 


4.575 


180 


59,491 
4,951 


312,228 
44,215 


8,794 


157,988 
83,725 


18,264 

35,277 


16,168 

750 


150,585 
5,251 


5,117 
232 


14,848 
85 








184 


1,254 




1,888 


214 


101 


33 


7,754 










5,135 


45,469 
1,075.374 




85,613 
2,363,779 


35,491 
509,984 


851 
78,098 


5,284 
529.411 


7,986 
40,588 


85 


158,007 


20,095 


53,826 


310,550 


2,694,013 


112,399 


4,524,957 


1,339,772 


172,715 


1,171,274 


169,493 


103,267 








116,000 


313,499 

1,319 

33,336 




80,500 

277 

12.417 


73,015 
3,341 
5,545 




36 


2,789 
38,065 




733 
555 


2,412 


1,270 


1,469 


57,243 








1,306 

158,007 


40,854 

1,075,374 
424 


1,469 
20,095 


173,243 

2,363,779 
6,450 


348,154 

509,984 
2,712 


1,288 

78,098 
301 


93,194 

529,411 
516 


81,901 

40,588 
150 


2,412 

53,826 
50 








158,007 
23,357 


1,075,798 
358,126 


20,095 
20,000 


2,370,229 
702,002 


512,696 

78,736 


78,399 
20,113 


529,927 
132,459 


40,738 
17,985 


53,876 
10,794 


127,880 


1.219,235 


70,835 


1,279,483 


400,186 


72,915 


415,694 


28,869 


36,185 




















151,237 


1,577,361 


90,835 


1,981,485 


478,922 


93,028 


548,153 


46,854 


46,979 


310,550 


2,694,013 


112,399 


4,524,957 


1,339,772 


172,715 


1,171,274 


169,493 


103,267 


78,100 
4,981 


720.716 
14,643 


36,758 

557 


1,267,929 
11,622 


407,288 
1,983 


39,678 
424 


344,568 
3,684 


67,677 

405 


25,641 
179 


83,081 


735,359 


37,315 


1,279,551 


409,271 


40,102 


348,252 


68,082 


25,820 


56,526 


495,821 


22,787 


865,265 


276.717 


24,486 


213,454 


31,227 


17.073 


11,838 
8,494 


51,430 

66,504 

1.158 

49,680 


3,133 

4,574 


132,794 
66,231 
33,968 
81,447 


25,509 
32,709 
29,330 
19.959 


4,357 
5,807 


21,895 

29.291 

9,460 

17,408 


7,587 

10,477 

7,667 

3,678 


2,432 
1,672 


2,317 


2,236 


3,222 


1,541 




















79,175 


664,593 


32,730 


1,179,705 


384,224 


37,872 


291,508 


60,636 


22,718 


3,906 


70,766 


4,585 


99,846 


25,047 


2,230 


56,744 


7,446 


3,102 


892 


7.678 


574 


8,947 


3,244 


492 


2,345 


828 


316 



188 



Municipal Electrical Service 

Municipal Electrical Utilities Financial 



Southern Ontario System— Continued 





Granton 
303 


Gravenhurst 
3,133 


Grimsby 
4,804 


Guelph 
38.323 


Hagersville 
2,087 


Hamilton 




261,114 






A. BALANCE SHEETS 

FIXED ASSETS 


$ 

16,321 
3,017 


$ 
222,437 
55,248 


$ 
294,009 
46,587 


$ 
3,942,818 
480,497 


$ 
142,461 
32,101 


$ 
22,892,001 


Accumulated depreciation. 


1,874,019 




13,304 
3,685 


167,189 


247,422 
25,899 


3,462,321 

525 


110,360 

4,759 

18,000 

896 


21,017,982 


CURRENT ASSETS 


2,341,543 


Investment in government securities 


37,000 
4,658 




422 


1.619 


44,298 


1,165,085 








4,107 


41,658 
5,462 


27,518 


44,823 
75,900 


23,655 
160 


3,506,628 




763,052 


Sinking fund on local debentures. . . 


41 








1.948 


18,163 


84 


91,652 










41 
26,242 


5,462 

201,441 


1,948 
119,700 


94,063 

2,822,772 


244 
281,018 


854,704 


Equity in Ontario Hydro Systems .... 


27,939,469 




43,694 


415,750 


396,588 


6,423,979 


415,277 


53,318,783 


LIABILITIES 


908 
91 
10 




44,000 
2,933 

4,871 


1,700,000 
86,899 
83,167 




1,118,000 




133 
2,624 




1,254,973 


Other 


1,480 


126,815 








1,009 

26,242 
56 


2,757 

201,441 
329 


51,804 
119,700 


1,870,066 

2,822,772 
206 


1,480 
281,018 


2,499,788 


RESERVES 

Equity in Ontario Hydro Systems. . 
Other 


27,939,469 
244,696 












26,298 

5,735 


201,770 
44,279 


119,700 
86,344 


2,822,978 
393,637 


281,018 
8,000 


28,184,165 


CAPITAL 


6,591,892 






Accumulated net income invested in 

plant or held as working funds . 

Frequency standardization expense 


10,652 


166,944 


138,740 


1.337,298 


124,779 


16,042,938 


















16,387 


211,223 


225,084 


1,730,935 


132,779 


22,634,830 








43,694 


415,750 


396,588 


6,423,979 


415,277 


53,318,783 



B. OPERATING STATEMENTS 

REVENUE 


8,207 
15 


113,782 
3,637 


155,901 
743 


1,860,520 
16,693 


97,166 
1,016 


15 750 820 


Other 


223 991 








8,222 


117,419 


156,644 


1,877,213 


98,182 


15,974,811 




EXPENSE 


4,672 


92,149 


105,102 


1,221,054 


66,036 


12,425,338 


Local generation 


Operation and maintenance 


566 

1,291 

308 

437 


12,156 
10,604 


9,493 

16,972 

3,975 

7,059 


189,212 
146,919 
136,187 
86,620 


11,903 
6,232 


961,733 
755,602 
113,705 


Fixed charges — interest and principal 


— depreciation 

— other 


6,102 


3,871 


483,324 


















7,274 


121,011 


142,601 


1,779,992 


88,042 


14,739,702 




Net income or net expense 


948 


3,592 


14,043 


97,221 


10,140 


1,235,109 


Number of customers 


119 


1,331 


1,737 


12,103 


771 


80,211 



Statements A and B 
Statements for the Year Ended December 31, 1960 



189 



Hanover 
4,348 


Harriston 
1,628 


Harrow 
1,842 


Hastings 
899 


Havelock 
1,271 


Hawkesbury 
8,730 


Hensall 
903 


Hespeler 
4,461 


Highgate 
382 


$ 
329,046 
97,456 


$ 
148.957 
26,547 


$ 
201,176 
37,838 


$ 

75,561 
22,180 


$ 

90.337 
24,085 


$ 
541,148 
86,145 


$ 
111.105 
28.335 


$ 
375,204 
42,077 


$ 

31,323 
11,740 


231,590 


122,410 

4,302 
6,895 
1,709 


163,338 

50 
11,000 

222 


53,381 

6,280 

11,417 

374 


66,252 

3,982 

42,255 

680 


455,003 
18.411 


82,770 

6.445 
4,000 
1,094 


333,127 

45,177 
40,000 
32,259 


19,583 
2,157 


62,000 


3,000 


5,258 


3,080 


150 


67,258 
15,891 


12,906 
100 


11,272 
3,920 


18,071 


46,917 


21,491 
24,018 


11.539 
26 


117,436 

270 


5,307 










555 








1,480 


1,649 


191 


520 














16,446 


100 
147,745 


3,920 

134,843 




1,480 
52,411 


25,667 
47,726 


217 
75,974 


790 
558,134 




357,454 


28,268 


34,552 


672,748 


283,161 


313,373 


99,720 


167,060 


549,887 


170,500 


1,009,487 


59,442 




2,300 






16,500 
672 
457 


203,000 

156 

6,108 








6,499 


4,269 

1.309 


332 
863 


118 
410 


928 
2,915 




3,000 


1.978 


115 


9,499 

357,454 
25 


4,278 
147.745 


5,578 

134.843 
31 


1,195 
28,268 


17,629 
52,411 


209,264 
47,726 


528 

75,974 
37 


3,843 
558,134 


115 
34,552 
















357,479 
80,162 


147,745 
28,408 


134.874 
12,000 


28,268 
21,000 


52,411 
46,400 


47,726 
82,000 


76,011 
12,000 


558,134 
77,571 


34,552 
5,000 


225,608 


102,730 


160,921 


49,257 


50,620 


210,897 


81,961 


369,939 


19,775 




















305,770 


131,138 


172,921 


70,257 


97,020 


292,897 


93,961 


447,510 


24,775 


672,748 


283,161 


313,373 


99,720 


167,060 


549,887 


170,500 


1,009,487 


59,442 


170,919 
4,360 


71,706 
1,713 


86,466 
1,995 


22,442 
624 


32,894 
1,990 


214,188 
908 


44,666 
554 


251,708 
3,820 


12,750 
300 


175,279 


73,419 


88,461 


23,066 


34,884 


215,096 


45,220 


255,528 


13,050 


130,269 


52,853 


58,296 


16,095 


19,312 


95.626 


33,289 


201,869 


7,767 


14,873 
15,380 


8.037 

6.133 

624 

3,695 


9,402 
9,920 


1,364 
4.469 


2.470 
4.357 
2.132 
2,595 


22,065 
31,130 
20.630 
13,220 


2,978 
3,380 


21,678 
10,613 


1,113 

922 


9,745 


4,850 


1.379 


3,188 


8.179 


1,040 




















170,267 


71,342 


82,468 


23,307 


30,866 


182,671 


42,835 


242,339 


10,842 


5,012 


2,077 


5,993 


241 


4,018 


32,425 


2,385 


13,189 


2,208 


1,602 


659 


674 


452 


458 


2,185 


366 


1.423 


165 



190 



Municipal Electrical Service 

Municipal Electrical Utilities Financial 



Southern Ontario System— Continued 



Municipality 


Holstein 
177 


Huntsville 
3.200 


Ingersoll 
7.174 


Iroquois 
1.014 


Jarvis 

755 


Kemptville 
1,914 






A. BALANCE SHEETS 

FIXED ASSETS 


$ 

13,010 
3,128 


$ 
216,636 
36,896 


$ 
578,879 
122,364 


$ 
195,903 
11,296 


$ 

58,396 
15,299 


$ 
132,872 




21,909 








9,882 

2,307 

500 

41 


179,740 

18,754 

24,925 

4.738 


456,515 
17,316 


184,607 

2,137 

21.000 

3,004 


43.097 
6,484 


110,963 


CURRENT ASSETS 


4.677 




12,000 


4.721 


402 


3,319 








2.848 


48,417 
7,952 


22,037 
16,686 


26,141 
1.125 


6,886 


19,996 




9,944 


Sinking fund on local debentures. . . 


40 








2,318 




















40 
11,133 


7,952 
289.447 


19,004 
723,706 


1.125 
39.008 




9,944 


Equity in Ontario Hydro Systems. . . • 


56,700 


114.681 




23,903 


525,556 


1,221,262 


250,881 


106,683 


255,584 


LIABILITIES 






52,013 

767 

10,016 














301 
1,665 




10,865 


Other 


43 


1,980 


75 


1,186 








43 
11.133 


1,980 
289.447 


62,796 

723,706 
99 


1,966 
39,008 


75 
56,700 


12,051 


RESERVES 

Equity in Ontario Hydro Systems. . 
Other 


114.681 
















11.133 
2,762 


289,447 
15,697 


723,805 
107,787 


39.008 


56.700 
10.500 


114,681 


CAPITAL 


19,507 








Accumulated net income invested in 
plant or held as working funds. 
Frequency standardization expense 


9,965 


218,432 


326.874 


209,907 


39,408 


109,345 


















12,727 


234,129 


434,661 


209,907 


49,908 


128,852 








23,903 


525,556 


1,221,262 


250,881 


106,683 


255,584 


B. OPERATING STATEMENTS 

REVENUE 


5.756 
24 


150,393 
1,889 


317,644 
3,536 


47,913 
648 


22,147 

7 


80 757 


Other. 


944 








5,780 


152,282 


321,180 


48,561 


22,154 


81,701 




EXPENSE 


4.434 


98,909 


209,736 


26,078 


15,027 


58.84S 


Local generation 


Operation and maintenance 


229 
662 


14,654 
9,183 


37,179 

28,288 

6,018 

15,504 


4,240 
8,192 


692 

1,551 


9.840 
7.666 


Fixed charges — interest and principal 


— depreciation 

— other 


356 


5,635 


4,077 


1,684 


3.376 


















5,681 


128,381 


296,725 


42,587 


18,954 


79,730 




Net income or net expense 


99 


23,901 


24,455 


5,974 


3,200 


1,971 


Number of customers 


96 


1,215 


2,353 


395 


285 


764 



Statements A and B 
Statements for the Year Ended December 31, 1960 



191 



Kincardine 
2,691 


Kingston 
48,028 


Kingsville 
3,089 


Kirkfield 
134 


Kitchener 
72,961 


Lakefield 
2,073 


Lambeth 
1,926 


Lanark 
875 


Lancaster 
612 


$ 
227,312 
57,486 


$ 
5,155,571 

1,277,243 


256,308 
60,376 


$ 

20,373 
3,920 


$ 
9,162,205 
1,677,123 


$ 
187,013 
39,661 


$ 
107,436 
20,766 


$ 

54,055 
5,344 


$ 

28,324 
8,905 


169,826 

4,367 
32,000 


3,878,328 

103,683 
575,635 
178,975 


195,932 

3,132 

23,500 

3,522 


16,453 

1,034 

2,000 

384 


7,485,082 
253,666 


147,352 

150 

32,000 

973 


86,670 
9,467 


48,711 

1,436 

10,000 

491 


19.419 

1.876 
9 500 


7.366 


353,537 


2,630 


1,499 


43,733 
439 


858,293 
189,728 


30,154 
1,102 


3,418 


607,203 

174,778 


33,123 
6,165 


12.097 


11,927 
111 


12,875 










740 


137,150 


147 


520 


6.301 


3,738 
















1,179 


326,878 

1.852,957 


1,249 
184,552 


520 
12,224 


181,079 
5,796,797 


9.903 
90,403 




111 
29,879 




211,214 


56.280 


24,218 


425,952 


6,916,456 


411,887 


32,615 


14,070,161 


280,781 


155,047 


90,628 


56,512 




1,340,000 

230,638 

6,383 






472,500 
259,263 
119,850 




11.146 
3,464 
1.486 






1,232 


116 
4,110 


188 
6 


2,811 
1,090 




83 


1.053 


190 


458 


2,285 

211,214 
40 


1,577,021 

1.852,957 
111,279 


4,226 

184,552 
326 


194 

12,224 
200 


851,613 

5,796,797 
271,288 


3.901 
90,403 


16,096 
56,280 


190 
29,879 


541 
24,218 












211,254 
60,000 


1,964,236 
464,839 


184,878 
33,500 


12,424 
5,766 


6,068,085 
1,854,744 


90,403 
33,500 


56,280 
21,354 


29,879 
7,317 


24,218 
8.917 


152,413 


2,910,360 


189,283 


14,231 


5,295.719 


152,977 


61,317 


53,242 


22.836 




















212,413 


3,375,199 


222,783 


19,997 


7.150,463 


186,477 


82,671 


60,559 


31,753 


425,952 


6,916,456 


411,887 


32,615 


14,070,161 


280,781 


155,047 


90,628 


56,512 


121,012 
2,072 


2,026.083 
43,254 


103,731 
2,064 


5,857 
111 


3,748,456 
44,771 


64,524 
2,225 


53.883 
263 


15,649 
922 


13,773 
530 


123,084 


2,069,337 


105,795 


5,968 


3,793,227 


66,749 


54,146 


16,571 


14,303 


84,637 


1.271.212 


67,164 


2,960 


2,288,117 


39,872 


36,163 


11,453 


10,348 


14,977 
7,111 


173,169 
244,086 
136,960 
142,782 


8,823 

14,994 

739 

6,978 


853 
651 


445,458 
250,748 
191,974 
197,954 


5,096 
10,166 


2,668 
4,013 
2,694 
2,802 


1,187 
1,473 


1,204 
2,177 


6,360 


541 


4,810 


1,280 


876 




















113,085 


1,968,209 


98,698 


5,005 


3,374,251 


59,944 


48,340 


15,393 


14,605 


9,999 


101,128 


7,097 


963 


418,976 


6,805 


5,806 


1,178 


302 


1.205 


15,497 


1,249 


102 


23,324 


729 


604 


281 


208 



192 



Municipal Electrical Service 

Municipal Electrical Utilities Financial 



Southern Ontario System— Continued 





Leamington 
8,602 


Lindsay 
11,052 


Listowel 
3,665 


London 
119,616 


London 
Twp. 
43,953 


Long 




Branch 
10,783 






A. BALANCE SHEETS 

FIXED ASSETS 


$ 
667,439 
147,190 


$ 

934,350 
171,747 


$ 
360,422 
115,750 


10,509,700 
2,587,025 


$ 

162.927 
30,278 


$ 

608,418 




63,250 








520,249 

22,910 
2,000 
4,239 


762,603 

8,112 

29,454 

4,458 


244,672 

40,197 

20,000 

960 


7,922,675 

122,253 
306,500 
396,324 


132,649 
4,120 


545.168 


CURRENT ASSETS 

Cash on hand and in bank 

Investment in government securities 


7,788 
3,000 


346 


19,234 








29,149 
21,247 


42,024 
18,959 


61,157 
661 


825,077 
312,583 


4,466 


30,022 






Sinking fund on local debentures. . . 










7,021 


214 


204 














21,247 
484,363 


18,959 
623,793 


661 
347,183 


319,604 
9,132,824 


214 
125,418 


204 


Equity in Ontario Hydro Systems. . . 


331,234 




1,055,008 


1,447,379 


653,673 


18,200,180 


262,747 


906,628 


LIABILITIES 


64,000 

915 

14,300 




42,992 
3,840 
5,447 


413,000 

415,964 

63,767 


20.312 

36 

1,083 






102 
7,883 


122 


Other 


9,788 








79,215 

484,363 
2,936 


7,985 
623.793 


52,279 
347,183 


892,731 

9,132,824 
301,153 


21,431 
125,418 


9,910 


RESERVES 

Equity in Ontario Hydro Systems. . 
Other 


331,234 
1,147 














487,299 
61,000 


623,793 
130,000 


347,183 
69,842 


9,433,977 
1,818,900 


125,418 
31,416 


332,381 


CAPITAL 


40,305 






Accumulated net income invested in 
plant or held as working funds. 
Frequency standardization expense 


427,494 


685,601 


184,369 


6,054,572 


84,482 


524,032 


















488,494 


815,601 


254,211 


7,873,472 


115,898 


564,337 








1,055,008 


1,447,379 


653,673 


18,200,180 


262,747 


906,628 


B. OPERATING STATEMENTS 

REVENUE 


362,286 
1,584 


455,611 
21,362 


161,268 
1,329 


4,015,853 
168,476 


94.987 
1,247 


387,851 


Other 


363 








363,870 


476,973 


162,597 


4,184,329 


96,234 


388,214 




EXPENSE 


244,510 


311,671 


122,251 


2,579,246 


71,306 


255,829 


Local generation 


Operation and maintenance. 


23,426 

36,252 

5,403 

17,332 


59,527 
43,437 


10,492 
11.533 
6,518 
6,711 


452,239 

369,941 

45,974 

292,448 


3,924 
7,916 
3,059 
4,190 


23,904 

35,166 

2,419 


Fixed charges — interest and principal 


—depreciation 

— other 


22.506 


13,696 


















326,923 


437,141 


157,505 


3,739,848 


90,395 


331,014 




Net income or net expense 


36,947 


39,832 


5,092 


444,481 


5,839 


57,200 


Number of customers 


3,280 


3,754 


1,528 


33,107 


997 


4,243 



Statements A and B 
Statements for the Year Ended December 31, 1960 



193 



L'Orignal 
1,145 


Lucan 
945 


Lucknow 
1,009 


Lynden 
530 


Madoc 
1,488 


Magneta- 
wan 
256 


Markdale 
1,113 


Markham 
4,319 


Marmora 
1,358 


$ 

79,697 

22,982 


$ 

74,865 

23,430 


$ 

92,015 
14,271 


$ 

32,877 
9,924 


$ 
134,990 
33,182 


$ 

24.605 
6,151 


$ 

64,613 
10,870 


$ 
304,880 
49,998 


$ 

92,451 
29,179 


56,715 
10 209 


51,435 

10,211 

5,500 

142 


77,744 

8.085 

9,000 

664 


22,953 

6,949 

2,000 

749 


101,808 

15,978 

21,775 

1,769 


18,454 

1,933 

8,920 

44 


53,743 

5.231 

5,592 

209 


254,882 


63,272 
5,690 






3,000 


826 


3,726 


616 


11,035 


15,853 
36 


17,749 


9,698 


39,522 
4,975 


10,897 
332 


11,032 


3,726 
907 


9,306 
2,527 












3,639 




1,180 




925 




150 


252 














3,639 


36 
73,265 


1,180 
89,674 




5,900 
60,181 


332 
2,907 


150 
52,488 


1,159 
123,660 


2,527 


7,542 


44,450 


42,642 


78,931 


140,589 


186,347 


77,101 


207,411 


32,590 


117,413 


383,427 


117,747 


20 000 










15,300 
18 




46,831 
4,900 
5,423 








1,146 


145 
17 




409 
652 




330 


779 


1,087 


1,175 










20,330 

7,542 


779 
73,265 


1,146 

89,674 
280 


162 
44,450 


1,087 
60,181 


15,318 
2,907 


1,061 

52,488 


57,154 

123,660 
187 


1,175 
42,642 
















7,542 
8,000 


73,265 
11,214 


89,954 
17,614 


44,450 
4,495 


60,181 
14,000 


2,907 
8,700 


52,488 
6,370 


123,847 
21,974 


42,642 
15,092 


43,059 


55,331 


77,633 


27,994 


132,143 


5,665 


57,494 


180,452 


58,838] 




















51,059 


66,545 


95,247 


32,489 


146,143 


14,365 


63,864 


202,426 


73,930 | 


M 78,931 


140,589 


186,347 


77,101 


207,411 


32,590 


117,413 


383,427 


117,747 



25,422 
574 


33,207 
369 


42,581 
283 


15,572 
223 


46,832 
2,293 


6,937 
329 


35,578 
56 


166,929 
1,031 


46,699 
362 


25,996 


33,576 


42,864 


15,795 


49,125 


7,266 


35,634 


167,960 


47,06lf 


13,453 


24,217 


28,463 


11,899 


32,377 


2.882 


26,647 


112,670 


27,792 


2,026 
2,781 
2,056 


687 
1,984 


3,255 
4,386 


581 
1,388 


1,573 
4.586 


536 

671 

2,174 

657 


2,907 
1,898 


8,596 

13.268 

6,067 

7,332 


7,388 
3,087 


2,263 


2,321 


2,244 


998 


3,720 


1,666 


1,706 


















22,579 


29,209 


38,348 


14,866 


42,256 


6,920 


33,118 


147,933 


39,973 


3,417 


4,367 


4,516 


929 


6,869 


346 


2,516 


20,027 


7,088 


358 


355 


471 


167 


596 


107 


440 


1,334 


522 



194 



Municipal Electrical Service 

Municipal Electrical Utilities Financial 



Southern Ontario System— Continued 





Martintovvn 
430 


Maxville 
813 


Meaford 
3,672 


Merlin 
612 


Merrick- 
ville 
891 


Merritton 




6,497 






A. BALANCE SHEETS 

FIXED ASSETS 


$ 

27,172 
6,848 


$ 

66,221 
10,712 


$ 
273,556 
59,474 


$ 

65,534 
22,743 


$ 

69,886 
4,355 


$ 
672,377 




83,824 








20,324 
9,537 


55,509 

4,475 

1,500 

817 


214,082 
28,870 


42,791 
9,726 


65,531 
1,862 


588,553 


CURRENT ASSETS 


3,876 


Investment in government securities 


87,000 


1,238 


2,053 


451 


4,937 


4,182 








10,775 


6,792 


30,923 
6,902 


10,177 
535 


6,799 


95,058 


OTHER ASSETS 


18,787 


Sinking fund on local debentures. . . 












828 




352 


193 


















7,730 
192,708 


535 
41,414 


352 
14,810 


18,980 


Equity in Ontario Hydro Systems. . • - 


11,208 


42,135 


1.268.542 




42,307 


104,436 


445,443 


94,917 


87,492 


1,971,133 


LIABILITIES 










14,600 

1.655 

825 






886 
126 




350 
5,376 


403 

158 


1,192 


Other 


147 


3,380 








1,012 

11,208 
81 


147 

42,135 
265 


5,726 

192,708 
100 


561 

41,414 
14 


17,080 
14,810 


4,572 


RESERVES 

Equity in Ontario Hydro Systems. . 
Other 


1,268.542 










11,289 
5.346 


42,400 
13,643 


192,808 
47,725 


41,428 
13,122 


14,810 
10,400 


1,268,542 


CAPITAL 


32,186 






Accumulated net income invested in 
plant or held as working funds . 
Frequency standardization expense 


24,660 


48,246 


199,184 


39,806 


45,202 


665.833 


















30,006 


61,889 


246,909 


52,928 


55,602 


698,019 








42,307 


104,436 


445,443 


94,917 


87,492 


1,971,133 



B. OPERATING STATEMENTS 

REVENUE 


8,549 
66 


24,131 
229 


146,605 
1,872 


19,340 

2,778 


24,500 

72 


842,780 


Other 


3,678 








8,615 


24,360 


148,477 


22,118 


24,572 


846,458 






EXPENSE 


5.429 


17,488 


105,792 


11.735 


16,037 


732,818 


Local generation 




Operation and maintenance 


271 
832 

782 


2.144 
1.165 


12,714 
12,123 


2,088 
4,343 


2,672 
2,457 
1,753 
1,660 


24,739 
33 944 


Fixed charges — interest and principal 




— depreciation 

— other 


1.669 


7,217 


2,090 


15,297 


















7,314 


22,466 


137,846 


20,256 


24,579 


806,798 




Net Income or net expense 


1,301 


1,894 


10,631 


1,862 


7 


39,660 


Number of customers 


125 


313 


1,510 


255 


355 


2,001 



Statements A and B 
Statements for the Year Ended December 31, 1960 



195 



Midland 
8.615 


Mildmay 
836 


Millbrook 
842 


Milton 
5,394 


Milverton 
1.075 


Mimico 
16,380 


Mitchell 
2.161 


Moorefield 
303 


Morrisburg 
1,912 


$ 
693.191 
237,027 


$ 

44,364 
5,962 


$ 

56,712 
11,255 


$ 
528.732 
86,427 


$ 

82,498 
16,918 


$ 
992,543 
226,110 


$ 
247.197 
53,718 


$ 

23.418 
6,444 


$ 
218,418 
25,344 


456.164 

2.363 
140,000 


38,402 

2,697 

12,500 

43 


45,457 

5,884 

11,000 

1,107 


442.305 
9,369 


65,580 

10.810 

13,000 

719 


766,433 

11,439 

115,000 

24,505 


193,479 

693 

23.000 

2,961 


16.974 

364 

1.000 

116 


193,074 

34,681 
11,000 


53.919 


2,887 


1.100 


196,282 
8,399 


15,240 


17.991 
983 


12,256 
4,977 


24,529 
60 


150,944 
20.053 


26.654 
11.336 


1.480 
20 


46,781 
5,918 








2,694 




1.334 


515 




1,564 


530 


228 












11.093 




2.317 
21,699 


5,492 
417,592 


60 
150,089 


21,617 
657,764 


11.866 
187.565 


248 
24.764 


5,918 


851.543 


30.542 


61.803 


1,515,082 


84,184 


87,464 


877,645 


240,258 


1,596,758 


419,564 


43,466 


307,576 








72,226 
2.823 
7,348 


11,800 
208 
282 


81,000 

4,158 

49,056 


16,100 

204 

1.472 






2,100 




89 
881 


12 
402 


665 


2.917 


220 


2.690 


5.017 

851.543 
501 


220 
30,542 


970 
21.699 


82,397 

417,592 
454 


12,290 
150,089 


134.214 

657,764 
816 


17,776 

187,565 
875 


414 
24,764 


3,355 
61,803 














852.044 
111.945 


30,542 
12,304 


21.699 
9,000 


418,046 
51,900 


150,089 
12,460 


658,580 
169.971 


188,440 
31,009 


24.764 
4,500 


61,803 
31,636 


546.076 


41,118 


55.795 


325,302 


65,419 


633,993 


182.339 


13,788 


210,782 




















658.021 


53,422 


64,795 


377,202 


77.879 


803,964 


213,348 


18,288 


242.418 


1,515,082 


84,184 


87,464 


877,645 


240,258 


1,596,758 


419,564 


43,466 


307,576 


315,203 
7,178 


26.079 

478 


24,144 
600 


242,949 
3,081 


53.588 
571 


467.117 
12,880 


110.409 
2.638 


10,650 
69 


67.886 
3,034 


322,381 


26,557 


24,744 


246,030 


54,159 


479,997 


113,047 


10,719 


70,920 


249,181 


19,887 


17.199 


159.501 


37,243 


324,047 


76.088 


8,633 


44,838 


33,010 
22,893 


3,011 
1,928 


3.055 
2,771 


20,613 

23,726 

7,057 

12,462 


4,587 
4,796 
1,199 
2,141 


26,785 

68,480 

9,585 

26.234 


10.198 

12.127 

1,892 

6.394 


712 
588 


10,944 
13.270 


13,493 


1,094 


1,462 


690 


5,036 




















318,577 


25,920 


24,487 


223,359 


49,966 


455,131 


106,699 


10,623 


74,088 


3,804 


637 


257 


22,671 


4,193 


24,866 


6,348 


96 


3./6S 


2,851 


305 


338 


1,720 


473 


6.641 


912 


124 


744 



196 



Municipal Electrical Service 

Municipal Electrical Utilities Financial 



Southern Ontario System— Continued 





Mount 

Brydges 

957 


Mount 
Forest 
2,571 


Napanee 
4,505 


Neustadt 
505 


Newboro 
291 






573 






A. BALANCE SHEETS 

FIXED ASSETS 


$ 

66,049 
9,376 


$ 
170.062 

37,377 


$ 
340,608 
71,985 


$ 

36,467 
13,453 


$ 

29,870 
5,308 


$ 
52,124 




16,925 








56,673 
3,048 


132,685 

17,642 

20,000 

3,790 


268,623 

100 
27,000 
18,344 


23,014 

794 

19,200 

351 


24,562 

281 

3,000 

295 


35,199 


CURRENT ASSETS 


4,623 


Investment in government securities 


3,000 


425 


335 








3,473 


41,432 
1,497 


45,444 
11,293 


20,345 


3,576 


7,958 






Sinking fund on local debentures. . . 


509 








50 


2,825 




1,996 


248 










509 
32,946 


1,547 
159,828 


14,118 
267,397 




1,996 
3,324 


248 


Equity in Ontario Hydro Systems. . . . 


25,885 


8,397 




93,601 


335,492 


595,582 


69,244 


33,458 


51,802 


LIABILITIES 


14,600 
3,683 

422 








8,897 

81 

129 


3,750 






11,465 
5,501 


170 
214 




Other 


911 


196 








18,705 

32,946 

94 

33,040 
4,602 


911 

159,828 


16,966 
267,397 


384 
25,885 


9,107 
3,324 


3,946 


RESERVES 

Equity in Ontario Hydro Systems. . 
Other 


8,397 
















159,828 
21,627 


267,397 
70,000 


25,885 
15,504 


3,324 
8,103 


8,397 


CAPITAL 


10,250 






Accumulated net income invested in 
plant or held as working funds. 
Frequency standardization expense 


37,254 


153,126 


241,219 


27,471 


12,924 


29,209 
















41,856 


174,753 


311,219 


42,975 


21,027 


39,459 








93,601 


335,492 


595,582 


69,244 


33,458 


51,802 



B. OPERATING STATEMENTS 

REVENUE 

Sales of electric energy 


25,376 
14 


98,211 
1,949 


172,434 
11,327 


10,841 
898 


6,725 
250 


18 381 


Other 


186 






Total revenue 


25,390 


100,160 


183,761 


11,739 


6,975 


18,567 




EXPENSE 


14,642 


71,943 


124,613 


10,000 


3,380 


9,529 


Local generation 


Operation and maintenance 


4,379 
2,777 
1,352 
1,528 


7,732 
8,571 


20,212 
26,044 


1,118 
1,852 


774 
1,067 
1,143 

776 


855 

2,108 

826 


Fixed charges — interest and principal 


— depreciation 

— other 


4,676 


8,909 


752 


980 


















24,678 


92,922 


179,778 


13,722 


7,140 


14,298 




Net Income or net expense 


712 


7,238 


3,983 


1,983 


165 


4,269 


Number of customers 


355 


1,018 


1,686 


205 


145 


192 



Statements A and B 
Statements for the Year Ended December 31, 1960 



197 



Newbury 
343 



$ 

22,871 
9,022 



13,849 

3,864 

6,500 

853 



11,217 
20 



193 



Newcastle 



1,198 



$ 
113,356 
27,068 



86,288 

950 

7,000 

240 



8,190 
2,251 



284 



New 

Hamburg 
2,100 



$ 
145,302 
28,507 



116,795 

6,776 

23,000 

1,300 



31,076 
1,959 



Newmarket 



8,055 



$ 
622,294 
124,602 



497,692 
45,823 
10,700 



56,523 
38 



158 



New 

Toronto 
11,664 



$ 
930,395 
165,387 



765.008 

129,609 

80,000 

7,852 



217.461 

20,768 

1,426 



Niagara 



2,669 



$ 
248,667 
44,452 



204,215 

12,257 
10,000 
2,311 



24,568 
13,752 



38 



Niagara 
Falls 
22,575 



2,297,192 
543,309 



1,753,883 

100,066 
55,000 
13,058 



168,124 

90,462 

2,240 



North York 

Twp. 

244,145 



$ 

19,366.785 

2,404,731 



16,962,054 

986,678 

10,000 

218,584 



1,215,262 

696,601 
436,073 
239,054 



Norwich 



1,705 



$ 
99,911 

28,138 



71,773 

4,578 
7,500 
2,524 

14,602 

5,812 



131 



213 
16,905 



2,535 
41,685 



1,959 

182,878 



196 
216,892 



22,194 
2,171,072 



13,790 
161,133 



92.702 
2,287,579 



1,371,728 
4,260,812 



42,184 



138,698 



332,708 



771,303 



3,175,735 



403,706 



4,302,288 



23,809,856 



5,943 
135,164 



227,482 



328 
100 



14,000 
262 
689 



10.000 
239 



59.653 
7.880 
7.196 



1,320 
20,403 



24,121 

25 

2,783 



262 

45,567 



8,029,349 
178,525 
653,337 



428 
16,905 



14,951 



41,685 
67 



10,239 



182,878 
34 



74,729 



216,892 
3,850 



21,723 



2,171,072 
60 



26,929 



161,133 
382 



45,829 



2.287,579 
1,170 



8,861,211 



4,260,812 
8,427 



16,905 
9.754 



41.752 
15,000 



182,912 
22,264 



15,097 



220,742 
35,255 

440,577 



2,171,132 
8.000 

974,880 



161,515 
56,387 

158,875 



2,288,749 
690,243 



4,269,239 



2,462,303 
436,073 



7,781,030 



2,400 
1,409 



3,809 



135,164 
161 



135,325 
13,756 

74,592 



24,851 



139,557 



475,832 



982,880 



1.967,710 



10,679,406 



88,348 



42,184 



138,698 



332,708 



771,303 



3,175,735 



403,706 



4,302,288 



23,809,856 I 227,482 



7,851 
346 


46,141 
782 


76,884 
833 


357,416 
2,035 


1,259,277 
8,812 


104,309 
1,318 


1,001,916 
6,995 


9,445,822 
112,615 


60,747 
2,384 


8,197 


46,923 


77,717 


359,451 


1,268,089 


105,627 


1,008,911 


9,558,437 


63,131 


4,533 


29,479 


55,805 


247,861 


1,103,348 


71,163 


628,180 


6,028,974 


37,818 


604 
822 


5,311 
5,230 
1,850 
2,963 


6,418 
4,965 
1,440 

3,774 


19,824 
18,125 
6,429 

15,754 


38,932 
54,713 


13,465 
8,675 
2,581 
6,297 


142,693 
75,522 


715,167 

804,789 
722,486 
434,029 


10,479 

5,111 

243 


495 


23,576 


63,531 


2,694 




















6,454 


44,833 


72,402 


307,993 


1,220,569 


102,181 


909,926 


8,705,445 


56,345 


1,743 


2,090 


5,315 


51,458 


47,520 


3,446 


98,985 


852,992 


6,786 


130 


469 


711 


2,726 


4,052 


1,068 


7,480 


79,727 


673 



198 



Municipal Electrical Service 

Municipal Electrical Utilities Financial 



Southern Ontario System — Continued 





Norwood 
1.110 


Oakville- 

Trafalgar 

40,540 


Oil Springs 
480 


Omemee 
813 


Orangeville 
4.643 


Orillia 




14,515 






A. BALANCE SHEETS 

FIXKD ASSETS 


$ 
104,024 
28,928 


$ 
3,475,563 
333,057 


$ 

60,143 
20,532 


$ 

65,976 
20,846 


$ 
292,276 
62,620 


$ 
4 501,507 




923,687 








75,096 

9,802 

15,000 

2,922 


3,142,506 
208,406 


39,611 

1,432 

11,000 

31 


45,130 


229,656 
1,176 


3 577 820 


CURRENT ASSETS 


102,847 


Investment in government securities 


11,000 
15 


105,978 


85,927 


3.106 


56,441 






27,724 


294,333 
94.991 


12,463 
524 


11,015 
2,893 


4.282 
6.179 


265 266 


OTHER ASSETS 


65 519 










39.029 


1,324 




35 


865 














134.020 
609,230 


1,848 
74,472 


2,893 
24.001 


6,214 
233,092 


66 384 


Equity in Ontario Hydro Systems. . . . 


40,367 


102,033 




143,187 


4,180,089 


128,394 


83,039 


473,244 


4,011,503 


LIABILITIES 




1,516,448 

19,207 

103,875 








970,000 






214 
40 


795 
237 


4.158 
3,247 


12,042 


Other 


964 


14,494 








964 
40,367 


1,639,530 

609,230 
4,119 


254 
74.472 


1,032 

24,001 
45 


7,405 

233,092 
50 


996,536 


RESERVES 

Equity in Ontario Hydro Systems. . 
Other 


102,033 
107,080 












40,367 
55,100 


613,349 
306,762 


74.472 
16,721 


24,046 
12,000 


233,142 
25,594 


209 113 


CAPITAL 


1 642 000 






Accumulated net income invested in 
plant or held as working funds . 
Frequency standardization expense 


46,756 


1,620,448 


36,947 


45.961 


207,103 


1,163,854 


















101,856 


1,927,210 


53,668 


57,961 


232,697 


2,805,854 








143,187 


4,180,089 


128,394 


83,039 


473,244 


4,011,503 



B. OPERATING STATEMENTS 

REVENUE 


31,142 
931 


1,813,304 
49,978 


16,821 
1,463 


24,630 
536 


176,641 
644 


739 758 


Other 


6,229 






32,073 


1,863,282 


18,284 


25,166 


177,285 


745,987 




EXPENSE 


22,686 


1,131,286 


11,142 


15,639 


117,554 


196 284 


Local generation 


141,424 


Operation and maintenance 


1.651 
2,250 


128,490 

170,697 

137,470 

72,387 


3,128 
3,103 


4,543 
2,670 


12,581 
13.302 


99,806 
83,019 
100,749 


Fixed charges — interest and principal 


— depreciation 

— other 


3,049 


1,167 


1,247 


7,878 


85,776 


















29,636 


1,640,330 


18,540 


24,099 


151,315 


707,058 




Net income or net expense 


2,437 


222,952 


256 


1,067 


25,970 


38,929 


Number of customers 


412 


10,840 


225 


302 


1,694 


5,421 



Statements A and B 
Statements for the Year Ended December 31, 1960 



199 



Orono 
897 


Oshawa 
60,135 


Ottawa 
281,542 


Otterville 
726 


Owen 
Sound 
17.657 


Paisley 
744 


Palmerston 
1,526 


Paris 
5.778 


Parkhill 
1,136 


$ 

64,532 
12,969 


$ 
6,359,326 
1,181,080 


$ 

28,839.737 

5,708,522 


53.306 
19,456 


% 
1,368,669 
225,392 


$ 

68,779 
16,379 


$ 
164,559 
41,948 


$ 
505.227 
124,743 


$ 

121.200 
19,783 


51,563 

1,131 
8,000 


5,178,246 

326,119 
400,000 
245,670 


23.131,215 

103,518 
543,000 
879,336 


33.850 
4.032 


1,143,277 

41,814 
70,000 
55,729 


52.400 

3.476 

14,000 

190 


122,611 
31,060 


380,484 
18,012 


101,417 

4,480 
6,000 


448 


213 


1,062 


2.581 


2,673 


9.579 
3,028 


971,789 
114,509 


1,525,854 
350,645 


4.245 


167,543 
44.322 


17,666 


4,122 
9,750 


20,593 
527 


13,153 
560 










40 


7,739 


102,995 




1.703 


390 




249 


59 










3,068 


122,248 
3.639.181 


453,640 
5,659,938 




46,025 

1,124,277 


390 
48,293 


9,750 
165,842 


776 
438,826 


619 


20.304 


38,161 


85.057 


84,514 


9,911,464 


30,770,647 


76,256 


2,481,122 


118,749 


302,325 


840,679 


200,246 




357,000 

249,872 

90,120 


5,376,000 

661,992 

882 




38,000 
41.144 
20.865 




15,000 

547 

1.223 


89,400 

413 

2,399 


8,500 




262 

254 


65 

412 


2,055 


360 


603 


360 

20.304 
84 


696,992 

3,639,181 
8,192 


6,038,874 

5,659,938 
459,069 


516 

38,161 
14 


100,009 

1,124,277 
1,930 


477 
48,293 


16,770 

165,842 
37 


92,212 
438,826 


11,158 
85,057 










20,388 
8,000 


3,647,373 
445,622 


6,119,007 
4,604,000 


38,175 
4,500 


1,126,207 
169,718 


48,293 
13,623 


165,879 
27,000 


438,826 
106,107 


85,057 
21,229 


55.766 


5,121,477 


14,008,766 


33,065 


1.085,188 


56,356 


92,676 


203,534 


82,802 




















63,766 


5,567,099 


18,612,766 


37.565 


1,254,906 


69.979 


119.676 


309,641 


104,031 


84,514 


9,911,464 


30,770,647 


76,256 


2,481,122 


118,749 


302,325 


840,679 


200,246 


27,965 
1.089 


2,855,956 
87,560 


10.149,428 
203,353 


22,152 
173 


630,491 
23,830 


26,664 
599 


59,942 
53 


204,954 
404 


52,964 
635 


29,054 


2,943,516 


10,352,781 


22,325 


654,321 


27,263 


59,995 


205,358 


53,599 


17,164 


2,058,850 


6,054,829 
218,868 
959,988 
717,233 
545.939 
725,389 
22,506 


15,224 


413,678 


16,413 


41,068 


131,079 


35,076 


2,191 
5,295 


176.697 

180,024 

59,838 

158,720 


1,376 
1,743 


78,723 

75,523 

8,720 

32,120 


1,880 
3.728 


6,214 

8,049 

860 

4,797 


20,352 
14,463 
9,200 
14,375 


4,950 
5,486 
1,022 


1.674 


1,731 


1,914 


2,968 


















26,324 


2,634,129 


9,244,752 


20,074 


608,764 


23,935 


60,988 


189,469 


49,502 


2,730 


309,387 


1,108,029 


2,251 


45,557 


3,328 


993 


15,889 


4,097 


364 


19,255 


87.629 


287 


6,125 


327 


625 


1.973 


498 



200 



Municipal Electrical Service 

Municipal Electrical Utilities Financial 



Southern Ontario System — Continued 





Parry- 
Sound 
6.057 


Pene- 

tanguishene 

4,856 


Perth 
5,831 


Peter- 
borough 
46,424 


Petrolia 
3.649 


Pickering 
1,764 








A. BALANCE SHEETS 

FIXED ASSETS 


$ 
837,456 
201,611 


282.424 
91,123 


% 
363,092 
103,422 


$ 
5,345,454 
1,236,753 


$ 
329,187 
88,693 


105,818 




17,968 








635,845 

20.220 
16.362 
3.770 


191,301 

11,087 

65,000 

1,749 


259,670 

12,442 

81,000 

4,332 


4,108,701 
88,798 


240,494 

5,543 
15,053 
10,093 


87,850 


CURRENT ASSETS 


4,905 








163,822 


2,010 








40,352 
4,284 


77,836 
801 


97,774 
9,633 


252,620 
65,119 


30,689 
15,267 


6 915 


OTHER ASSETS 










1,139 




5,200 


302 


3,163 












4,284 
59,290 


1,940 
251,435 


9,633 

346,400 


70,319 
2,399,427 


15,569 
344,109 


3 163 


Equity in Ontario Hydro Systems. . . . 


5,079 




739,771 


522,512 


713,477 


6,831,067 


630,861 


103,007 


LIABILITIES 

Debentures outstanding 


66,000 
3,538 
9,067 






925,700 

129,746 

6,321 




73,000 


Accounts payable 


154 
1,823 




2.878 
6.448 


1,669 


Other 


4,542 


1,533 






78,605 

59,290 
2.456 


1,977 

251,435 
913 


4,542 

346,400 
159 


1.061,767 

2.399,427 
1,859 


9,326 

344,109 
14 


76.202 


RESERVES 

Equity in Ontario Hydro Systems . . 
Other 


5,079 
98 






Total reserves 


61.746 
402.500 


252,348 
36,983 


346,559 
85,045 


2,401,286 
833,911 


344,123 
50,000 


5,177 


CAPITAL 

Debentures redeemed 


823 


Local sinking fund 




Accumulated net income invested in 
plant or held as working funds. 

Frequency standardization expense 
charged this year 


196,920 


231,204 


277,331 


2,534,103 


227,412 


20,805 


















599,420 


268,187 


362,376 


3,368,014 


277,412 


21 628 








739,771 


522,512 


713,477 


6,831,067 


630,861 


103,007 


B. OPERATING STATEMENTS 
REVENUE 

Sales of electric energy 


201,173 

1,548 


125,883 
3,728 


181,488 
4,800 


1,985,551 
9,193 


123,404 
2.700 


55 807 


Other 


570 






Total revenue 


202,721 


129,611 


186,288 


1,994,744 


126,104 


56,377 




EXPENSE 


73.568 
32,377 
26,060 
27.358 
5.933 
16,684 


86,463 


140,318 


1,231,175 


64.304 


27,227 


Local generation 


Operation and maintenance 


15,681 
12,354 


12,981 
19,430 

6,286 


237.992 

138.529 

93,688 

146,129 


21,449 
21,779 


3,395 
4 854 


Fixed charges — interest and princirral 


7,180 


— depreciation 

— other 


8,759 


9,225 


2,664 
















Total expense 


181,980 


123,257 


179,015 


1,847,513 


116,757 


45,320 


Net Income or net expense 


20,741 


6,354 


7,273 


147,231 


9,347 


11,057 


Number of customers. 


1,978 


1,415 


1,994 


14,757 


1.309 


487 



Statements A and B 
Statements for the Year Ended December 31, 1960 



201 



Picton 
5,062 


Plattsville 
484 


Point 

Edward 

2.714 


Port 

Burwell 

716 


Port 

Colborne 

15,024 


Port Credit 
6,564 


Port 

Dalhousie 

3,325 


Port Dover 
3,096 


Port Elgin 
1,723 


$ 
437,143 
113,838 


45.514 
2,444 


$ 
264,371 
52,299 


$ 

75,993 
26,846 


1,022,376 

95,408 


$ 
632,216 

85,598 


$ 
246,810 
18,525 


290,879 
70,483 


186,710 
25,938 


323,305 

569 
2,000 


43,070 

2.384 
4.500 

227 


212,072 

2,473 

49,282 

6,639 


49,147 
4,688 


926,968 

13,636 

10,000 

1,628 


546,618 

1.368 

62.503 

7,370 


228,285 
4,459 


220,396 
10,889 


160,772 

8,014 
1,500 


3.278 


422 


9,478 


1,130 


1,890 


5.847 
13.107 


7,111 
26 


58,394 
298 


5,110 
248 


25,264 
12,326 


71,241 
6,739 


13,937 
6,951 


12,019 
266 


11,404 
4,379 






2,307 


1,043 


11,283 


3,188 


10 


44 










13,107 
299.992 


26 
48,772 


2,605 
346,357 


1.291 
17,779 


23,609 
554,681 


9,927 
339,363 


6,961 

178,072 


310 
145,324 


4,379 
99,454 


642,251 


98,979 


619,428 


73,327 


1,530,522 


967,149 


427,255 


378,049 


276,009 


26,852 






32,600 

10 

3,292 


115,833 

864 

12.265 


47,100 

6,210 

21,370 


21,000 

519 

3,034 


69,075 

553 
8,189 




6,119 




22,453 
1,708 


200 


10,532 












43,503 




24,161 

346,357 
100 


35,902 
17,779 


128,962 
554,681 


74,680 

339,363 
221 


24,553 

178,072 
290 


77,817 
145,324 


200 


299,992 
55 


48,772 


99,454 
108 














300,047 
36,330 


48,772 
5,237 


346,457 
17,000 


17,779 
7,400 


554,681 
227,167 


339,584 
90,861 


178,362 
48,500 


145,324 
39,452 


99,562 

37,787 


262,371 


44,970 


231,810 


12,246 


619,712 


462,024 


175,840 


115.456 


138,460 




















298.701 


50.207 


248,810 


19,646 


846,879 


552,885 


224,340 


154.908 


176,247 


642,251 


98,979 / 


619,428 


73,327 


1,530,522 


967,149 


427,255 


378,049 


276,009 



191,954 
2,728 


29,665 
233 


167,614 
4,994 


24,622 

758 


400,275 
2,681 


526.122 
7.456 


107,964 
2,067 


125,805 
47 


88,532 
806 


194,682 


29,898 


172,608 


25,380 


402,956 


533,578 


110,031 


125,852 


89,338 


128,356 


26,020 


149,432 


9,537 


232,334 


434,397 


62.655 


81,455 


46,018 


13,538 
14,402 

7,564 


1,566 
628 


7,582 

21,410 

323 

6,697 


4,872 
2,672 
2,942 
2,488 


46,957 
50,848 
15,902 
22,438 


16,146 
28,063 
11,595 
14,769 


16,061 

19,514 

2,569 

5,037 


12,051 

10,286 

6,309 

8,138 


12.087 
10.229 


12,082 


966 


4,348 




















175,942 


29,180 


185,444 


22,511 


368,479 


504,970 


105,836 


118,239 


72,682 


18,740 


718 


12,836 


2,869 


34,477 


28,608 


4,195 


7,613 


16,656 


1,798 


195 


807 


462 


4.614 


2,774 


1,079 


1.558 


1,064 



202 



Municipal Electrical Service 

Municipal Electrical Utilities Financial 



Southern Ontario System — Continued 





Port Hope 
8,072 


Port 

McNicoll 

1.016 


Port Perry 
2.247 


Port Rowan 
795 


Port 

Stanley 

1.442 






5,235 




A. BALANCE SHEETS 

FIXED ASSETS 


$ 
745 868 
143.144 


$ 

78,289 
11,977 


$ 
143,878 
24,914 


$ 

64,480 
11,792 


$ 
182,786 
56,178 


310 426 




85 094 








602,724 
43,434 


66,312 

4,243 

26,000 

4,862 


118,964 

4,621 

26,550 

1,041 


52,688 
1.046 


126.608 

597 
9.000 

3.782 


225 332 


CURRENT ASSETS 






30 000 




2,035 


886 


24,118 






45,469 
26,151 


35,105 
1,352 


32,212 


1,932 
236 


13,379 
705 


54 118 


OTHER ASSETS 


9 376 


Sinking fund on local debentures. . . 






Miscellaneous 


346 


120 




















26,151 

502,749 


1,698 
60,934 


120 
94,915 


236 

31,875 


705 
165,391 


9 376 


Equity in Ontario Hydro Systems. . . . 


266,364 




1,177,093 


164,049 


246,211 


86,731 


306,083 


555,190 


LIABILITIES 


88,000 












Accounts payable 






706 
286 


180 
973 


9,508 


Other 


42,295 


402 


1,771 


3 448 








130.295 
502,749 


402 
60,934 


1,771 

94,915 
100 


992 
31,875 


1,153 

165,391 
39 


12 956 


RESERVES 

Equity in Ontario Hydro Systems. . 
Other 


266,364 














502,749 
156,000 


60,934 
9,804 


95,015 
19,882 


31,875 
11,000 


165,430 
18,950 


266,364 


CAPITAL 

Debentures redeemed 


23,981 


Local sinking fund 




Accumulated net income invested in 
plant or held as working funds. 

Frequency standardization expense 
charged this year 


388,049 


92,909 


129,543 


42,864 


120,550 


251,889 
















Total capital 


544,049 


102,713 


149,425 


53,864 


139,500 


275,870 








1,177,093 


164,049 


246,211 


86,731 


306,083 


555,190 


B. OPERATING STATEMENTS 

REVENUE 

Sales of electric energy 


403,722 
1,732 


53,448 
1,557 


64,420 

1,827 


16.874 

87 


73,593 
526 


164,506 


Other 


2.157 




Total revenue 


405,454 


55,005 


66,247 


16,961 


74,119 


166,663 






EXPENSE 

Power purchased 


271,462 


39,292 


49,772 


10.363 


43,073 


117 992 


Local generation 




Operation and maintenance. 

Administration 


39,646 
38,631 
20,778 
18,154 


4.603 
3.460 


6,138 
6,919 


1,576 
1,666 


8,763 

8,740 


9.844 
17 110 


Fixed charges — interest and principal 


1.460 


— depreciation 

— other 


1.900 


3,611 


1,564 


5,433 


9.138 
















Total expense. 


388,671 


49,255 


66,440 


15,169 


66,009 


155,544 




Net income or net expense 


16,783 


5,750 


193 


1,792 


8,110 


11,119 


Number of customers 


2,824 


495 


833 


319 


1.137 


1.745 



Statements A and B 
Statements for the Year Ended December 31, 1960 



203 



Preston 
11,338 


Priceville 
155 


Princeton 
438 


Queenston 
448 


Renfrew 
8,409 


Richmond 
1,183 


Richmond 

Hill 

16,095 


Ridgetown 
2,612 


Ripley 
442 


$ 
1,137,470 
226,630 


$ 

15,898 
5,290 


$ 

32,936 
6,538 


$ 

41.567 
6,795 


$ 
1,330,022 
266,488 


$ 

86,708 
6,097 


$ 
1.098,510 
93,990 


$ 
193,036 
31,816 


$ 

37.057 
7,250 


910.840 

43,326 
30,000 


10,608 

1.818 

5,500 

79 


26,398 

2,856 

3,000 

344 


34,772 

4,209 

8,000 

341 


1,063,534 

35,875 
45,000 
33,115 


80,611 
2,615 


1,004,520 
14,866 


161,220 

7,189 

10,071 

2,232 


29.807 

7,584 
15 000 


9,008 


7,023 


31,193 


46 


82,334 
38,630 


7,397 
25 


6,200 


12,550 


113,990 
14,267 


9,638 
14 


46,059 
20,221 


19,492 
113 


22.630 










1,459 


2 70 






1,247 




12,090 


3,354 














40,089 


295 
4,407 






15,514 
125,786 


14 
23,446 


32,311 
233.182 


3,467 

166,937 




1,001,194 


38.002 


30,621 


34.933 


2,034,457 


22,707 


70,600 


77,943 


1,318,824 


113,709 


1,316,072 


351,116 


87,370 


206,640 


3,300 
148 
83 


1.750 
122 
310 




180,221 
15,037 
14,233 


6,200 

20,011 

925 


539,557 
52,473 
36,254 


47,842 
2.089 
5,769 




5,340 
14,656 


182 
145 


77 
473 


226,636 
1,001,194 


3,531 
4,407 


2,182 

38,002 


327 

30,621 

55 


209,491 

125.786 
165 


27,136 
23,446 


628,284 

233,182 
1,700 


55,700 

166,937 
206 


550 
34,933 












1,001,194 
269,643 


4,407 
8.866 


38,002 
4,245 


30,676. 
9,500 


125.951 
591,016 


23,446 
7,687 


234.882 
80.898 


167,143 
33,614 


34,933 
12.744 


536,984 


5.903 


26,171 


37,440 


392,366 


55,440 


372,008 


94,659 


39.143 




















806,627 


14,769 


30,416 


46,940 


983,382 


63,127 


452,906 


128,273 


51,887 


2,034,457 


22,707 


70,600 


77,943 


1,318,824 


113,709 


1,316,072 


351,116 


87,370 


518,444 
5,531 


3,744 
266 


14,297 
125 


18,374 

450 


286,366 
5,246 


29,878 

2 


556,719 
4.961 


93.853 
1,681 


16,193 
638 


523,975 


4,010 


14,422 


18,824 


291,612 


29,880 


561,680 


95,534 


16,831 


344,322 


1,889 


10,509 


13,530 


139,548 
36,046 
19,994 
29,855 
19,794 
31,549 


18.581 


370,500 


57,281 


11,627 


63,088 
28,182 
27,871 


585 
450 
431 
514 


506 

1,037 

370 

874 


1,645 

1,177 


1,806 

1,340 

825 

1,732 


28,944 
33.664 
49.205 
22,537 


9,166 
11,457 
5.200 
4.874 


1,168 
1,412 


29,682 


1,044 


985 




















493,145 


3,869 


13,296 


17,396 


276,786 


24,284 


504,850 


87,978 


15,192 


30,830 


141 


1,126 


1,428 


14,826 


5,596 


56,830 


7,556 


1,639 


3,360 


62 


174 


183 


2,716 


331 


4,712 


1.046 


217 



204 



Municipal Electrical Service 

Municipal Electrical Utilities Financial 



Southern Ontario System — Continued 





Riverside 
17,549 


Rockland 
2,919 


Rockwood 
897 


Rodney 
1,067 


Rosseau 
228 






556 






A. BALANCE SHEETS 

FIXED ASSETS 


$ 
811,262 
169,454 


$ 
107,831 
8,468 


48,437 
10,241 


$ 

61,689 
22,139 


$ 

24,170 
5,947 


$ 
41,899 




8,145 








641.808 
7.020 


99,363 
4.024 


38,196 

4,933 

1,500 

129 


39,550 

1,211 

5,200 

397 


18.223 

2.094 
1.500 
1,070 


33,754 


CURRENT ASSETS 


4,717 




12,000 




15,942 


2,694 


1,883 








22.962 

22,963 

3,905 


6,718 


6,562 


6,808 
26 


4,664 

84 


18,600 


OTHER ASSETS 














2,451 


63 


















26,868 
429,527 


2,451 
17,355 


63 
46,004 


26 
56,473 


84 
14,934 




Equity in Ontario Hydro Systems. . . . 


24,756 




1,121,165 


125,887 


90,825 


102,857 


37,905 


77,110 


LIABILITIES 


54,142 

464 

16,795 


19,000 
3,802 
2,492 


6.545 
364 
680 










1,013 
500 




283 


Other 


43 


330 






Total liabilities 


71,401 

429,527 
433 


25,294 

17,355 
546 


7.589 
46,004 


1,513 

56,473 
73 


43 

14,934 

27 


613 


RESERVES 

Equity in Ontario Hydro Systems. . 
Other 


24,756 










429,960 
141,258 


17,901 
6,000 


46,004 

5,784 


56,546 

8.500 


14,961 
11,933 


24,756 


CAPITAL 


8,808 






Accumulated net income invested in 
plant or held as working funds. 
Frequency standardization expense 


478,546 


76.692 


31,448 


36,298 


10,968 


42,933 


















619,804 


82,692 


37,232 


44,798 


22,901 


51,741 








1,121,165 


125,887 


90,825 


102,857 


37,905 


77,110 



B. OPERATING STATEMENTS 

REVENUE 

Sales of electric energy 


388,042 
3,123 


51,204 
171 


23,506 
176 


29,608 

375 


7.353 

175 


12,675 


Other 


648 








391,165 


51,375 


23,682 


29,983 


7,528 


13,323 






EXPENSE 


248,231 


32,065 


17,757 


18,822 


3,903 


9,231 


Local generation 




Operation and maintenance 


38,805 
46,490 
13,839 
20,939 


7.107 
3,290 
1,877 
2,448 


3,080 

2,785 

589 

1,337 


4,938 
5,551 


789 
673 


1,381 
1,554 


Fixed charges — interest and principal 




— depreciation 

— other 


2,010 


711 


1,087 


















368,304 


46,787 


25,548 


31,321 


6,076 


13,253 




Net Income or net expense 


22,861 


4,588 


1,866 


1,338 


1,452 


70 


Number of customers 


5,346 


736 


291 


445 


127 


209 



Statements A and B 
Statements for the Year Ended December 31, 1960 



205 



St. 

Catharines 

41,163 


St. Clair 
Beach 
1,416 


St. George 

754 


St. Jacobs 
715 


St. Mary's 
4,509 


St. Thomas 
22,348 


Sandwich 

East Twp. 

21,864 


Sandwich 

West Twp. 

27,786 


Sarnia 
49,089 


$ 
4,200,871 
609,169 


$ 
101,726 
21, 956 


$ 
50.426 

3,447 


$ 

49,459 
10,351 


% 
482.383 
118,496 


$ 
1,725,477 
472,930 


$ 
1,397,639 

277,149 


$ 
2,018,259 
346,223 


$ 
4,766,740 
969,984 


3,591,702 
413,078 


79,770 
8,571 


46,979 


39,108 

2,246 
6,703 
1,244 


363,887 

24,428 

42.500 

2.283 


1,252,547 

300 
35,000 
59,571 


1,120,490 

129,177 
13,170 
44,449 


1,672,036 

19,662 

148,919 

87,344 


3,796,756 
600 


100,000 


6.000 
1.538 




171,053 


1,115 


126,805 


684,131 
91,789 


9,686 

28 


7,538 
65 


10,193 
10 


69,211 
22,804 


94,871 
43.944 


186,796 
35,373 


255,925 
29,622 


127,405 
173,888 


2,680 


259 






23 


2,258 


43,729 


61,333 


49,255 










94,469 
3,691,369 


287 
35,800 


65 
53,873 


10 
68,770 


22.827 
519,038 


46.202 
1.825.214 


79,102 
193,005 


90,955 
348,802 


223.143 
3,498,588 


8,061,671 


125,543 


108,455 


118,081 


974,963 


3,218,834 


1,579,393 


2,367,718 


7,645,892 




5,400 

682 

1,210 






42,934 

831 

3,869 




918,000 
41,535 
35,991 


1,114,000 

2,326 

98,587 


678,500 


181.085 
23,399 


202 
696 


577 
100 


20,184 
48.470 


154,817 
63,044 


204,484 

3,691,369 
9,234 


7,292 
35.800 


898 
53,873 


677 
68,770 


47,634 

519.038 
12 


68.654 

1,825,214 
234 


995,526 

193.005 
908 


1,214,913 

348,802 
100 


896,361 

3.498,588 
2,433 












3,700,603 
302,023 


35,800 
12,553 


53,873 
6.000 


68,770 
6,000 


519,050 
147,274 


1,825,448 
138,944 


193,913 
125,829 


348,902 
181,500 


3,501,021 
607,891 


3.854,561 


69,898 


47,684 


42,634 


261,005 


1,185,788 


264,125 


622,403 


2,640,619 




















4.156,584 


82,451 


53,684 


48,634 


408,279 


1,324,732 


389,954 


803,903 


3,248,510 


8,061,671 


125,543 


108,455 


118,081 


974,963 


3,218,834 


1,579,393 


2,367,718 


7,645,892 


2,383,924 
20,911 


38,218 
158 


23,342 
389 


26,842 
231 


478,658 
4,146 


857,329 

7,322 


604,075 
8,004 


853,389 
12,072 


6,054,562 
50,200 


2,404,835 


38,376 


23,731 


27,073 


482,804 


864,651 


612,079 


865,461 


6,104,762 


1.592,576 


22,991 


19,801 


21,121 


401,675 


520,552 


232,994 


425,863 


5,163,831 


180,412 
168,772 


1,987 
3,504 
1,551 
2,632 


1,102 
1,835 


1,245 
1,580 


22,168 

20,233 

5,519 

13,257 


134,055 
80,897 


107,638 
85,165 
86,033 
35,058 


86,340 

87,139 

108,255 

50,061 


364,122 

220,430 

78,748 


101,097 


1,075 


1,331 


49,346 


121,438 















2,042,857 


32,665 


23,813 


25,277 


462,852 


784,850 


546,888 


757,658 


5,948,569 


361,078 


5,711 


82 


1,796 


19,952 


79,801 


65,191 


107,803 


156,193 


14.105 


429 


303 


227 


1,646 


7.033 


6,191 


7,862 


15.419 



206 



Municipal Electrical Service 

Municipal Electrical Utilities Financial 



Southern Ontario System— Continued 





Scarborough 

Twp. 

197,969 


Seaforth 
2,260 


Shelbume 
1.247 


Simcoe 
8.453 


Smith's 
Falls 
9,082 






835 






A. BALANCE SHEETS 

FIXED ASSETS 


$ 

18,539,923 
1,801,352 


$ 

229,127 
26,046 


$ 

115,901 
34,106 


$ 

706,005 
147,183 


$ 

763,483 
199,743 


$ 

64 095 




12 431 








16.738.571 

876.482 
327.500 
434,885 


203,081 

13,682 
9,000 
4,457 


81,795 

11,737 
5.954 
1,011 


558.822 

25.581 

24.525 

2.073 


563.740 

1.806 

20,000 

3.606 


51.664 

8 907 


CURRENT ASSETS 


Investment in government securities 


3.000 
127 








1.638.867 

144,855 
569.159 
228,825 


27,139 

495 


18,702 
270 


52,179 
1.089 


25,412 
16.933 


12 034 


OTHER ASSETS 


226 


Sinking fund on local debentures. . . 




39 


1,200 


132 


413 










942,839 
3,446,713 


534 
214,858 


1,470 
89.031 


1.221 
552,539 


17,346 
546,534 


226 


Equity in Ontario Hydro Systems. . . , 


33.341 




22,766,990 


445,612 


190,998 


1,164,761 


1,153,032 


97,265 


LIABILITIES 


9,392,554 

731,824 

1.148,140 


25,700 
1,600 

2,775 






7,500 
3.797 

852 






349 
166 




24 


Other 


10,938 


360 








11,272.518 

3,446,713 
11,088 


30.075 
214,858 


515 

89,031 
100 


10,938 
552,539 


12,149 

546,534 
81 


384 


RESERVES 

Equity in Ontario Hydro Systems. . 
Other 


33.341 












3,457,801 

1,807,573 
569,159 

5,659,939 


214,858 
48,740 


89,131 
16,991 


552,539 
75,435 


546,615 
140,288 


33,341 


CAPITAL 


15.000 






Accumulated net income invested in 
plant or held as working funds. 
Frequency standardization expense 


151,939 


84,361 


525,849 


453,980 


48.540 


















8,036,671 


200,679 


101.352 


601,284 


594,268 


63.540 








22,766,990 


445,612 


190,998 


1,164,761 


1,153,032 


97,265 



B. OPERATING STATEMENTS 

REVENUE 


7.310.532 
158,108 


86,625 

722 


50.297 
82 


392.058 
3,971 


337,206 
2.849 


39,607 


Other 


352 








7,468,640 


87,347 


50,379 


396,029 


340,055 


39,959 






EXPENSE 


4,827,311 


56,549 


31,661 


280,189 


226.810 


24,192 


Local generation 




Operation and maintenance 


445,657 
557,319 
764,761 
395,965 


10,841 

10,275 

2,900 

5,165 


3,597 
3,405 


43,535 
22.170 


26,997 

37,181 

3,390 

21,866 


3,215 
5,059 


Fixed charges — interest and principal 




— depreciation 


3.482 


18,635 


1,674 


















6,991,013 


85,730 


42,145 


364,529 


316,244 


34,140 




Net Income or net expense 


477,627 


1,617 


8,234 


31,500 


23,811 


5,819 


Number of customers 


59,815 


865 


570 


3.139 


3,330 


375 



Statements A and B 
Statements for the Year Ended December 31, 1960 



207 



Southamp- 
ton 
1.716 


Springfield 

536 


Stamford 
Twp. 
29,655 


Stayner 
1,624 


Stirling 
1,328 


Stoncy 
Creek 
6,130 


StouffviUe 

3.052 


Stratford 
20.432 


Strathroy 

4,844 


$ 
173.576 

17.Q55 


$ 
39,791 

13,077 


$ 
2.411.344 
J.N, 0-4 J 


$ 
121.969 

:o,ooo 


$ 
122.718 
35,781 


$ 

350,868 
38,284 


S 
203.522 

J ■5.0-45 


$ 
2.275.647 
501,768 


$ 

418.837 
1JJ.47S 


155.621 

11.272 
5 000 


26.714 

5.297 

1 .500 

519 


2.076,402 

231,283 

8.000 

28,543 


101.960 

6,016 
1,000 
1 ,654 


86,937 

14.893 


312.584 

12.136 

20,760 

1.394 


177.877 
28.968 


1,773.879 

25.460 

180.000 

21.620 


296,359 
754 


2.746 


5,195 


7.538 


2,464 


19.018 
3,149 


7.316 


267,826 
47,837 


8.670 
221 


20,088 
1,810 


43.290 


30.506 
379 


227.080 
70.078 


3,218 
516 














28,259 


965 




900 


2.187 


22.277 


643 










3,149 




76,096 
722,698 


1,186 
80,946 


1,810 
57.793 


900 
90.698 


2.566 
110.222 


02.355 
2.081.097 


1.159 


94,746 


31.878 


364.03 2 


272,534 


65,908 


3,143,022 


192,762 


166,628 


447,472 


327,171 


4,174,411 


664,768 


6,658 




1,006.377 
45,037 
56,267 




5,951 


46.946 

1.811 
6.142 


65.362 

7,518 
0.411 


328,000 

36.3 71 
02.207 


6,600 


72 


585 
145 


727 
511 


2.913 


1.435 


828 


4.002 


8,165 
94,746 


730 

31,878 
350 


1.107.681 

722.698 
1.200 


1,238 

80.946 
100 


6.779 
57.793 


54,899 
90,698 


82,291 

110.222 
74 


456,578 

2. 081.097 
1.158 


14.475 

364.032 
66 










94,746 

35,865 


32,228 

9.500 

23,450 


723,898 
563.901 


81,046 

9,557 


57.793 
17.049 


90,698 
31,514 


110,296 

10,030 


2.082.255 
455.800 


364,098 

5 7.280 


133,758 


747.542 


100.921 


85.007 


2 70.361 


115.545 


1,179,778 


228,000 




















169,623 


32,950 


1,311.443 


110.478 


102.056 


301,875 


134.584 


1,635,578 


286.105 


272,534 


65,908 


3,143,022 


192,762 


166,628 


447,472 


M7.171 


4,174,411 


664,768 


79.158 
1.840 


11,913 
94 


1,050,853 
9.430 


62,656 

150 


44.786 

788 


188.723 
1.444 


% 

110,062 
1.444 


005.012 
8,485 


105.448 
350 


80,998 


12,007 


1,060,283 


62,806 


45,574 


190,167 


120,506 


914,397 


195,807 


43,983 


8,663 


608,617 


36,362 


20.072 


130.1 OS 


78,950 


557.158 


124.425 


13.100 
5,802 
1.517 


1.109 
1,356 


109,608 
84.619 

101.993 
56.956 


4,614 

3.50') 


6,111 

(..711 

999 

2.103 


11.124 
19,686 

6.202 
8.151 


6.560 

10.55 7 

5,194 

1,380 


103.46 7 
91,476 
24,911 
61,021 


23.107 

21.055 

1.272 


3,820 


1.248 


2,969 


12,336 




















68,222 


12,376 


961,793 


47,454 


45,119 


184,361 


105,650 


838.033 


182.195 


12,776 


369 


98,490 


15,352 


455 


5,806 


14,856 


76,364 


13.612 


1.158 


182 


8.931 


648 


536 


1.952 


1,066 


(.,078 


1.80 7 



208 



Municipal Electrical Service 

Municipal Electrical Utilities Financial 



Southern Ontario System — Continued 





Streetsville 
4,979 


Sunderland 
611 


Sundridge 
765 


Sutton 
1,405 


Swansea 
9,529 






506 






A. BALANCE SHEETS 

FIXED ASSETS 


$ 
357,261 
45,962 


$ 

44,236 
9,719 


$ 

68.821 
8,221 


$ 
140,607 

36,555 


$ 
652,350 
134,464 


$ 
41,747 




10,755 








311.299 
10,510 


34,517 

8,301 

2,000 

282 


60.600 

9,569 

9,934 

476 


104,052 

2,910 
7,000 
5,123 


517,886 

61,939 

98,217 

4,080 


30,992 


CURRENT ASSETS 


4 860 


Investment in government securities 


8,000 


4,608 


174 








15,118 
966 
142 


10,583 


19,979 
690 


15,033 


164.236 
10,564 


13,034 


OTHER ASSETS 


50 


Sinking fund on local debentures. . . 








99 




4,406 


1,906 


172 










1,108 
90.063 


99 
41,881 


690 
9,066 


4,406 
92,165 


12,470 
480,911 


222 


Equity in Ontario Hydro Systems. . . . 


37,278 




417,588 


87,080 


90,335 


215,656 


1,175,503 


81,526 


LIABILITIES 


110.955 

1.517 

18.401 




24,892 

1,552 

41 




71,382 
8,437 
17.202 






115 
100 


6,161 
1,186 




Other 


15 








130,873 

90,063 
1,293 


215 
41,881 


26,485 
9,066 


7,347 

92,165 
265 


97,021 

480,911 
200 


15 


RESERVES 

Equity in Ontario Hydro Systems. . 
Other 


37,278 












91,356 
42,064 


41,881 
4,628 


9,066 
10,108 


92,430 
26,000 


481,111 
177,765 


37,278 


CAPITAL 


14,264 






Accumulated net income invested in 
plant or held as working funds. 
Frequency standardization expense 


153,295 


40,356 


44,676 


89,879 


419,606 


29,969 


















195,359 


44,984 


54,784 


115,879 


597,371 


44,233 








417,588 


87,080 


90,335 


215,656 


1,175,503 


81,526 



B. OPERATING STATEMENTS 

REVENUE • 


173,575 
1,666 


19,490 
202 


24,683 
744 


62,419 
382 


317,693 
17,819 


20,543 


Other 


302 








175,241 


19,692 


25,427 


62,801 


335,512 


20,845 






EXPENSE 


111,978 

1,167 

7,132 

11,917 

11,411 

8,521 


15,519 


11,625 


40,496 


233,258 


15,156 






Operation and maintenance 


1,079 
1,640 


2,044 
1,866 
2,809 
1,416 


5,575 
7,875 


51,206 
35,028 
13,728 
16,355 


1,273 
1,069 


Fixed charges — interest and principal 
— depreciation 




1,211 


4,038 


1,219 


















152,126 


19,449 


19,760 


57,984 


349,575 


18,717 




Net income or net expense 


23,115 


243 


5,667 


4,817 


14,063 


2,128 


Number of customers 


1,445 


262 


296 


890 


3,528 


235 



Statements A and B 
Statements for the Year Ended December 31, 1960 



209 



Tavistock 
1,222 


Tecumseh 
4,416 


Teeswater 
895 


Thamesford 
984 


Thamesville 
1.040 


Thedford 
738 


Thornbury 
1,161 


Thorndale 
416 


Thornton 
289 


$ 
106,618 
33,079 


$ 
225.719 
65,075 


$ 

83,458 
12,940 


$ 

76,145 

13,559 


$ 
101.965 
23,718 


$ 

55,457 
8,837 


$ 
146,124 
15,519 


$ 

30,666 
10,379 


$ 

20,595 
. 8,590 


73,539 

12,913 
10 000 


160,644 
9.923 


70,518 


62,586 
952 


78.247 

8,667 

6,840 

847 


46,620 

1,666 

11,927 

1,383 


130,605 

338 
4.000 
4.208 


20.287 

5,959 

3,000 

911 


12,005 
1,149 


15,000 
74 




247 


6,045 


1,098 


550 


23,160 
303 


15,968 
11,399 


15,074 


2,050 


16,354 
14 


14,976 
14 


8,546 
1,797 


9.870 


1.699 












58 




628 


69 


87 


570 


286 




233 










361 


11,399 
127,989 


628 
56,737 


60 
69,652 


101 
75.749 


584 
43,852 


2,083 
23.102 




233 


165.033 


32,610 


13,359 


262,093 


316,000 


142,957 


134,357 


170,451 


106,032 


164,336 


62,767 


27,296 


21,273 






2.100 

177 
541 






22,736 
711 

275 






598 


116 
2,000 


1,145 
79 




2,418 
529 


101 
6 


88 


1,187 


1.095 


78 


23,058 
165,033 


2,116 
127,989 


1,224 
56,737 


2,818 
69,652 


1,095 

75,749 
131 


2,947 

43,852 
5 


23,722 
23,102 


107 

32,610 

28 


166 
13,359 














165,033 
14,012 


127,989 
26,000 


56,737 
21,296 


69,652 
6,258 


75,880 
11,188 


43,857 
16,500 


23,102 
63,264 


32,638 
3,086 


13,359 
7.200 


59,990 


159,895 


63,700 


55,629 


82,288 


42,728 


54,248 


26,936 


6,571 




















74,002 


185,895 


84,996 


61,887 


93,476 


59,228 


117,512 


30,022 


13.771 


262,093 


316,000 


142,957 


134,357 


170,451 


106,032 


164,336 


62,767 


27,296 


50,839 
2,180 


93,733 
700 


35,114 
695 


41,217 
439 


43,313 
415 


21.716 

572 


54.907 
317 


13,655 
193 


6,855 

1 


53,019 


94,433 


35,809 


41,656 


43,728 


22,288 


55,224 


13,848 


6,856 


33,972 


52,829 


26,095 


29,553 


29,630 


17.578 


31,608 


9,792 


4,263 


5,803 
3,787 
2,260 


14.379 
13.414 


2,267 
2,498 


2,257 

2,688 

177 

1,890 


5,135 
4,515 


1.567 
2,133 


6,146 
4,055 
2,890 
3,198 


1,317 
1.485 

980 


668 

544 


3,204 


6,582 


2,138 


2,775 


1,352 


442 




















49,026 


87,204 


32,998 


36,565 


42,055 


22,630 


47,897 


13,574 


5,917 


3,993 


7,229 


2,811 


5,091 


1,673 


342 


7,327 


274 


939 


510 


1,337 


360 


352 


442 


315 


534 


137 


103 



210 



Municipal Electrical Service 

Municipal Electrical Utilities Financial 



Southern Ontario System — Continued 





Thorold 
8.602 


Tilbury 
3,070 


Tillsonburg 
6,542 


Toronto 
657,233 


Toronto 
Twp. 
59,983 






781 






A. BALANCE SHEETS 

FIXED ASSETS 


$ 
593.521 
93,530 


$ 
231,760 
66,740 


$ 
732,002 
84.277 


$ 
95.719,614 
24,776,628 


$ 
6,175,881 
618,023 


$ 
37,639 




9,400 








499,991 
30,001 


165,020 

8,163 
10,000 
3,028 


647,725 
7,619 


70.942,986 

110,587 
3,380,007 
4,465,928 


5,557,858 

27.665 

8,000 

346,363 


28 239 


CURRENT ASSETS 


9,006 




10,584 




2,692 


2.886 


743 








32,693 
16.222 
3,315 


21,191 
456 


10.505 
21,722 


7,956,522 

2,587,383 
611,858 
540,608 


382,028 
97,034 


20,333 


OTHER ASSETS 










791 


12,062 


73,930 










19,537 
647,078 


1,247 
220,434 


33.784 

383,281 


3,739,849 
78.668,476 


170,964 
1,551,088 




Equity in Ontario Hydro Systems. . . • 


44,061 




1,199,299 


407,892 


1,075,295 


161,307,833 


7,661,938 


92,63* 


LIABILITIES 

Debentures outstanding. 


92.581 
3,307 
6,175 


40,000 

202 

4.860 


92,600 

6,926 

22,179 


13.724,050 

2,381,731 

915.427 


1,064,564 

83,783 

132.251 


2,369 






Other 


733 








102,063 

647,078 
200 


45,062 

220,434 
381 


121,705 

383,281 
79 


17.021,208 

78,668.476 
751,960 


1,280,598 

1,551,088 
17,324 


3,102 


RESERVES 

Equity in Ontario Hydro Systems. . 
Other 


44,061 






Total reserves 


647,278 
37,418 


220,815 
24,000 


383.360 
123,400 


79,420,436 

31,203,935 
611,858 

33,050,396 


1,568,412 
536,804 


44,061 


CAPITAL 


19.065 






Accumulated net income invested in 
plant or held as working funds. 
Frequency standardization expense 


412,540 


118,015 


446.830 


4,276,124 


26,405 


















449,958 


142,015 


570.230 


64,866,189 


4,812,928 


45,470 








1,199,299 


407,892 


1,075,295 


161,307,833 


7,661,938 


92,633 



B. OPERATING STATEMENTS 

REVENUE 


545,624 
6,728 


89,370 
1,254 


273,940 
1,010 


37,251,067 
423,988 


3,024,299 
25,960 


22,109 


Other 


404 






Total revenue 


552,352 


90,624 


274,950 


37,675,055 


3,050,259 


22,423 






EXPENSE 


448,623 


53,890 


167,406 


22,661.713 


2,025,171 


15,232 






Operation and maintenance 


41,290 

31,400 

9,753 

14,569 


8,179 
14.561 
4,703 
6,796 


35,176 
23,245 
15,752 
16,471 


5,240,304 
4,162,918 
1,253,285 
3,055,273 


212,803 
232,470 
116,352 
135,008 


1,345 
1,135 


Fixed charges — interest and principal 
— depreciation 


838 
1,075 


















545,635 


88,129 


258,050 


36,373,493 


2,721,804 


19,625 




Net income or net expense 


6,717 


2,495 


16,900 


1,301,562 


328,455 


2,798 


Number of customers 


2,566 


1,053 


2,450 


208,956 


15,130 


271 



Statements A and B 
Statements for the Year Ended December 31, 1960 



211 



Trenton 
12,314 


Tweed 
1.717 


Uxbridge 
2,369 


Vankleek 
Hill 
1,690 


Victoria 

Harbour 

999 


Walkerton 
3.835 


Wallaceburg 
8,029 


Wardsville 
313 


$ 
1,040,561 
279,256 


$ 

149.545 
20,265 


$ 
147,955 

25,957 


$ 
129,958 
24,223 


$ 

61,322 

10,398 


$ 

262,913 
25,768 


$ 
902,103 
238,234 


$ 

26,507 
6,806 


761.305 
15,064 


129,280 


121,998 

16,278 

22,375 

927 


105,735 
8,058 


50,924 
2.169 


237.145 

17,004 

23,000 

4,022 


663,869 

100,378 
75,396 
30,004 


19,701 
1,171 


55,200 


24.500 
293 


1 500 


17,971 


9 


1,346 


219 


88,235 
22,402 


24,793 

524 


39,580 

2,318 


8,067 


3,515 
1,724 


44.026 
13,466 


205,778 
68,688 


2,890 








100 


600 




1.686 




590 
















22.502 


1.124 
71.958 


2.318 
108.811 


1,686 
11,921 


1,724 
28,927 


14,056 
168,774 


68,688 
948,034 




749,667 


17,716 


1,621,709 


227,155 


272,707 


127,409 


85,090 


464,001 


1,886,369 


40,307 








34,300 

737 

2,049 


9,600 








4,891 


5.866 

552 


4,131 
2,032 


858 
2,690 


361 
7,683 


185 


14,082 


145 


170 


18.973 

749,667 
300 


6,418 

71,958 
310 


6,163 

108,811 
206 


37.086 
11,921 


9,745 
28,927 


3,548 

168,774 
638 


8,044 

948,034 
1,301 


355 

17,716 

7 










749,967 
164,587 


72,268 
19,000 


109,017 
15,364 


11,921 
11,700 


28.927 
9,278 


169,412 
56,749 


949,335 
71,537 


17.723 
7,562 


688,182 


129,469 


142,163 


66,702 


37,140 


234,292 


857.453 


14,667 


















852.769 


148,469 


157,527 


78,402 


46,418 


291,041 


928.990 


22,229 


1,621,709 


227,155 


272,707 


127,409 


85,090 


464,001 


1,886,369 


40,307 



667.808 
5.882 


44,797 
1,776 


87,045 
1,068 


41.066 
743 


25.339 

147 


131,620 
2,178 


404,894 
6.217 


11,545 
219 


673,690 


46,573 


88,113 


41,809 


25,486 


133,798 


411,111 


11,764 


529,129 


36,919 


63,976 


21,321 


13,444 


91,350 


292.662 


7,324 


32,993 
42.340 


2,622 
5,234 


7.751 
7.140 


3.282 
4,821 
3.536 
3,344 


3,639 
2,041 
1,164 
1,549 


11,525 
15,999 


42.684 
42.111 


595 
680 


29.019 


3,519 


3.672 


5.890 


26.179 


756 


















633,481 


48,294 


82,539 


36,304 


21,837 


124,764 


403,636 


9,355 


40,209 


1,721 


5,574 


5,505 


3,649 


9,034 


7,475 


2,409 


4,078 


624 


888 


544 


494 


1,295 


2,744 


148 



212 



Municipal Electrical Service 

Municipal Electrical Utilities Financial 



Southern Ontario System — Continued 





Warkworth 
524 


Wasaga 

Beach 

414 


Waterdown 
1,834 


Waterford 
2,155 


Waterloo 
20,562 


Watford 




1,235 






A. BALANCE SHEETS 

FIXED ASSETS 


$ 

50.103 
7,936 


$ 
164.351 
41,167 


$ 
120,038 
29,134 


$ 
134,444 
27,960 


$ 

1.904,416 
359,542 


$ 
90,827 




29,967 








42,167 

1.457 

3.000 

106 


123.184 

7,056 
15,000 
6,509 


90.904 
11.801 


106,484 

2.221 
9,917 

473 


1,544,874 

10.199 

100 

15.562 


60,860 


CURRENT ASSETS 


10,926 




13,148 




1.038 


3,312 








4.563 


28,565 


12.839 

52 


12,611 

77 


25.861 
51.892 


27,386 


OTHER ASSETS 


617 












2.917 






406 


















2,917 
17.206 


52 
89,880 


77 
123,581 


52,298 
1,229,740 


617 


Equity in Ontario Hydro Systems. . . . 


21.244 


111,609 




67,974 


171,872 


193,675 


242,753 


2,852,773 


200,472 


LIABILITIES 


7,504 
484 
202 


68,000 

130 

4,125 


9,000 


32,600 


513,500 
20,326 
32,016 




Accounts payable 


98 


Other 


576 


2,972 


811 








8,190 
21,244 


72.255 

17,206 
147 


9,576 
89,880 


35.572 
123,581 


565,842 

1,229,740 
41 


909 


RESERVES 

Equity in Ontario Hydro Systems. . 
Other 


111,609 














21,244 
11.496 


17,353 
42,000 


89,880 
13,632 


123,581 
9.523 


1,229,781 
336,127 


111,609 


CAPITAL 


9,056 


Local sinking fund 




Accumulated net income invested in 
plant or held as working funds. 

Frequency standardization expense 
charged this year 


27,044 


40,264 


80,587 


74,076 


721,023 


78,898 


















38.540 


82.264 


94,219 


83,600 


1.057,150 


87,954 








67,974 


171,872 


193,675 


242,753 


2,852,773 


200,472 


B. OPERATING STATEMENTS 

REVENUE 

Sales of electric energy 


12.677 

108 


57,113 
1,825 


61,789 
101 


64,606 
118 


882,416 
3,584 


66,662 


Other 


1,381 






Total revenue 


12,785 


58,938 


61,890 


64,724 


886,000 


68,043 




EXPENSE 


8,509 


25,936 


37,178 


38,719 


575,263 


53 344 


Local generation 




Operation and maintenance 


955 
1.509 

642 
1.161 


6.617 
8.460 
7,960 
4,382 


5,989 
5,806 
1,491 
3,367 


7,520 
4,365 
2,917 
3,523 


80,125 
50,691 
60,066 
47,298 


4.672 
7.958 


Fixed charges — interest and principal 


— depreciation 

— other 


2,826 


















12,776 


53,355 


53,831 


57,044 


813,443 


68,800 




Net income or net expense 


9 


5,583 


8,059 


7,680 


72,557 


757 


Number of customers 


236 


1.038 


589 


823 


6.445 


524 



Statements A and B 
Statements for the Year Ended December 31, 1960 



213 



Waubaushene 
1.400 


Welland 
17,556 


Wellesley 
670 


Wellington 
1.002 


West Lome 
1,077 


Weston 
9.419 


Westport 
693 


Wheatley 
1,337 


$ 

50.241 
8,590 


$ 
1.776,846 
409,231 


$ 

50,055 
6,694 


$ 

72.449 

26,592 


$ 
108,684 
33,190 


$ 
1,151.485 
214,805 


$ 

40,225 
4,051 


$ 

149,882 
25,076 


41.651 
701 


1,367.615 

58.244 

122.146 

8.438 


43,361 

3,029 

1,000 

13 


45.857 

229 

9.000 

361 


75,494 

17,834 
4,925 
1,768 


936.680 
65.422 


36,174 

1.447 
8,000 


124,806 
8,854 


1,042 


14.913 


374 








1.743 
312 


188,828 
22,663 


4,042 
15 


9.590 
2,050 


24,527 
1,596 


80.335 

31,149 

26,266 

4,141 


9,447 


9,228 
181 










47.767 






591 


15 












312 
25.126 


70,430 
1,486,317 


15 
56,191 


2,050 

55,452 


2,187 
114.754 


61,556 
990,576 


15 
29.892 


181 
74,055 


68,832 


3,113,190 


103,609 


112,949 


216,962 


2,069,147 


75,528 


208,270 




482.000 
11.786 
27,009 


3,800 

1,000 

196 






177,513 
16,414 
25,029 




22,004 


1.023 


88 
864 


186 
155 




215 


35 


299 


1,351 


1.058 
25.126 


520.795 

1,486,317 
23.430 


4,996 
56,191 


952 

55,452 


341 

114,754 

7 


218,956 

990,576 

784 


299 
29.892 


23,570 

74,055 
1 












25.126 
3.242 


1,509,747 
347,250 


56,191 
8,628 


55,452 
13,816 


114,761 
8,000 


991,360 

127,287 
26,266 

705,278 


29,892 
15,000 


74,056 
29,996 


39,406 


735,398 


33,794 


42,729 


93,860 


30,337 


80,648 


















42,648 


1,082,648 


42.422 


56,545 


101,860 


858,831 


45,337 


110,644 


68,832 


3,113.190 


103,609 


112,949 


216,962 


2,069,147 


75,528 


208,270 



21.559 
64 


759,534 
14.150 


24,792 
29 


27,766 
692 


57.322 
3,751 


503,153 
20,610 


19.171 
514 


58,965 
137 


21,623 


773,684 


24,821 


28,458 


61,073 


523,763 


19,685 


59,102 


11,615 


510,303 


16,475 


22,995 


38,088 

3,435 
7,151 


325,534 


13,140 


34,502 


3.474 
2.306 


80,156 
69.404 
43,455 
48,935 


1,717 

1,440 

479 

1,215 


3,924 
2.907 


40.736 
58.144 
19.792 
28.959 


1,486 
3,125 


5,101 
3.867 
3,624 


1.236 


1,449 


3,236 


910 


3,690 


















18,631 


752,253 


21,326 


31,275 


51,910 


473,165 


18,661 


50,784 


2,992 


21,431 


3,495 


2,817 


9,163 


50,598 


1,024 


8,318 


443 


5,496 


278 


497 


428 


3.398 


293 


490 



214 



Mu n icipal Electrical Service 

Municipal Electrical Utilities Financial 



Southern Ontario System — Concluded 





Whitby 
12,501 


Wiarton 
2,038 


Williams- 
burg 

336 


Winchester 
1.379 


Windermere 
1 19 






116.160 






A. BALANCE SHEETS 

FIXED ASSETS 


$ 
1,157,366 
180,457 


$ 
123,325 
18,703 


$ 

21,758 
6,858 


$ 
105,946 
23,814 


$ 

30,433 
7,369 


$ 
12,192 367 




3,907,531 








976.909 

35,252 
10,000 
20,659 


104,622 

1,416 

15,000 

680 


14,900 

1,179 

15,000 

149 


82,132 
20,529 


23,064 

7,991 

5,000 

192 


8 284 836 


CURRENT ASSETS 


51 670 




1,970,439 




1,086 


412,893 








65,911 

29,133 
290 


17,096 
41 


16,328 


21,615 


13.183 


2,435,002 


OTHER ASSETS 


233,739 






















1,390 
















29,423 
400,350 


41 
95,347 








235,129 


Equity in Ontario Hydro Systems. . . • 


25,943 


98,370 


13.298 


12,500,184 




1,472,593 


217,106 


57,171 


202,117 


49,545 


23,455,151 


LIABILITIES 


156,000 

43 

149,996 














86 
172 




99 

10 


246 


262,858 


Other 


413 


178,684 










306,039 

400,350 
1,000 


258 
95,347 


413 

25,943 
311 


109 
98,370 


246 

13.298 
90 


441,542 


RESERVES 

Equity in Ontario Hydro Systems. . 
Other 


12,500,184 
247,426 












401,350 
120,356 


95,347 
37,400 


26,254 
2,750 


98,370 
29,206 


13.388 
11,238 


12,747,610 


CAPITAL 


2,583,832 






Accumulated net income invested in 
plant 01 held as working funds. 
Frequency standardization expense 


644,848 


84,101 


27,754 


74,432 


24,673 


7,682,167 


















765,204 


121,501 


30,504 


103,638 


35,911 


10,265,999 








1,472,593 


217,106 


57,171 


202,117 


49,545 


23,455,151 


B. OPERATING STATEMENTS 

REVENUE 


532,318 
6,182 


67,021 
1,056 


9,478 

573 


64,917 

87 


8,201 
233 


4,444,164 


Other 


1 12 158 






Total revenue 


538,500 


68,077 


10,051 


65,004 


8,434 


4,556,322 






EXPENSE 


336,097 


51,940 


8,546 


43,222 


4,951 


2,905,188 


Local generation 


Operation and maintenance. 


39,852 
62,339 
27,335 
26,968 


10,001 
6,059 


312 
990 


2,603 
4,143 


1,102 
770 


739,300 

384,498 

9,188 


Fixed charges — interest and principal 


— depreciation 

— other 


3,002 


674 


2,895 


863 


372,757 


















492,591 


71,002 


10,522 


52,863 


7,686 


4,410,931 




Net income or net expense 


45,909 


2,925 


471 


12,141 


748 


145,391 


Number of customers 


3,732 


791 


147 


558 


120 


37.142 



Statements A and B 
Statements for the Year Ended December 31, 1960 



215 



Wingham 
2.770 


Woodbridge 
2.293 


Woodstock 
19.923 


Woodville 
422 


Wyoming 
876 


York Twp. 
123,457 


Zurich 
737 


Total 

Southern 

Ontario 

System 


$ 

284.390 
89,195 


$ 

163,890 
36,248 


$ 

1,875,695 
479,073 


$ 

34,432 
5,041 


$ 

58.662 

17,000 


$ 
7,252,130 
2,045,445 


$ 

50,419 
6,695 


392.734,743 
78,008,709 


195.195 

17.225 
60 000 


127,642 

38,112 

24,575 
519 


1,396,622 

141.422 

135,000 

18,484 


29,391 
4,582 


41,662 

9,224 

9,155 

764 


5,206,685 

299,345 
554,000 
245,028 


43.724 
1.055 


314,726,034 

11,283.117 
13,370,776 


1.503 


396 


69 


12,241,073 


78.728 
11 068 


63,206 
98 


294,906 
899 


4.978 


19,143 

98 


1,098,373 
102,353 


1,124 
62 


36,894.966 
8.688,312 






2,316,958 


1,123 




1,611 


267 




3,970 


9 


2,414,256 










12.191 
193,159 


98 
180,538 


2,510 
1,743,836 


267 
34.478 


98 
37,682 


106,323 
4,202.471 


71 
51,499 


13,419,526 
247,826,004 


479,273 


371,484 


3,437,874 


69,114 


98,585 


10,613,852 


96,418 


612,866,530 






48,638 
10,265 
27,809 










71,355,033 


588 


2,206 
2,865 


6,131 

50 


10 
118 


251.919 
457,604 




9,267,653 


3.368 


190 


6,668,147 


3,956 

193,159 
107 


5,062 

180,538 
141 


86,712 

1,743,836 
408 


6,181 

34.478 
472 


128 

37,682 
64 


709,523 

4,202,471 
49,242 


190 

51,499 
15 


87,290,833 

247,826,004 
2,783,591 


193,266 

81,155 


180,679 
23,835 


1,744.244 
380,565 


34.950 
5.248 


37,746 
9,700 


4,251,713 
489,375 


51,514 
5.592 


250,609.595 

78.253.470 
2,316,958 


200,896 


161,908 


1,227.455 
1,102 


22,735 


51,011 


5,163,241 


39,122 


194,402,110 
6,436 
















282,051 


185.743 


1.606,918 


27.983 


60.711 


5,652,616 


44.714 


274,966,102 


479,273 


371,484 


3,437,874 


69,114 


98,585 


10,613,852 


96,418 


612,866,530 



116,206 

7,573 


109,919 
1,825 


977.443 
11,860 


14,459 
44 


23,766 
628 


3,316.025 
37.986 


26,455 

5 


177.430,093 
2,559,190 


123,779 


111,744 


989,303 


14,503 


24,394 


3,354,011 


26,460 


179,989,283 


82,557 
2.543 


82,886 


667.485 


5.563 


16,312 


2.316,186 


16.523 


116,983,928 
516,699 


10.191 
13.159 


2,744 

8,057 

533 

4.608 


102,674 
50,680 
36,734 

52,842 


1,863 
1.016 


1,587 
1,430 


323.855 
438.647 


2,482 
2,440 


17.301,943 

14,863.076 

7,048,240 


8,637 


794 


1,740 


210,802 


1.182 


10,306,237 
22,506 


















117,087 


98,828 


910,415 


9,236 


21,069 


3,289,490 


22,627 


167,042,629 


6,692 


12,916 


78,888 


5,267 


3,325 


64,521 


3,833 


12,946,654 


1,045 


754 


6,798 


197 


330 


40,423 


304 


1,273,866 



216 



Northern Ontario Properties 



Municipal Electrical Service 

Municipal Electrical Utilities Financial 





Atikokan 
Twp. 
7,456 


Cache Bay 
896 


Capreol 
2,730 


Chapleau 
Twp. 
3,696 


Cochrane 
4,368 






2,569 






A. BALANCE SHEETS 
FIXED ASSETS 


$ 
492,449 
69,128 


$ 

55,191 
10,325 


$ 
208,041 
31,017 


$ 
138.304 
5,635 


$ 
405,371 
67,297 


$ 
111,094 




10 316 








423,321 

55,211 

50,000 

8,097 


44,866 

1,674 

11,804 

1,668 


177,024 
22,244 


132,669 
20,507 


338,074 
25,124 


100 778 


CURRENT ASSETS 


10 240 








1,520 


4,309 


1,947 


14 627 








113,308 

2,220 

13,062 


15,146 
458 


23,764 


24,816 


27,071 
11,778 


24,867 


OTHER ASSETS 












1,307 


4,743 


5,936 


10.475 


393 








15,282 
58,530 


1,765 
652 


4,743 
1,554 


5.936 


22,253 
1,934 


393 














610,441 


62,429 


207,085 


163,421 


389,332 


126,038 


LIABILITIES 


348,000 

5,116 

40,005 


8,000 


86,200 

950 

2,983 


95,000 
1,241 
3,361 


93,000 

5,278 
12.087 


43,500 




15,242 


Other 


105 


7,471 








393,121 
58.530 


8,105 

652 
66 


90,133 

1,554 
470 


99,602 


110,365 

1,934 
232 


66,213 


RESERVES 

Equity in Ontario Hydro Systems. . 




Other 


123 


324 










58,530 
52,000 


718 
20,000 


2,024 
35,800 


123 
20,000 


2.166 
52,000 


324 


CAPITAL 


6 500 


Local sinking fund 




Accumulated net income invested in 
plant or held as working funds. 
Frequency standardization expense 


106,790 


33,606 


79,128 


43,696 


224,801 


53,001 


















158,790 


53,606 


114,928 


63,696 


276,801 


59,501 








610,441 


62,429 


207,085 


163,421 


389,332 


126,038 


B. OPERATING STATEMENTS 

REVENUE 


271,342 
5,666 


28,368 
546 


105,745 
270 


138,864 
19 


173,509 
3,949 


58,692 


Other 


210 








277,008 


28,914 


106,015 


138,883 


177,458 


58,902 






EXPENSE 


193,754 


19,318 


70,906 


83,873 


90,629 


36,215 






Operation and maintenance 


14,907 
32,052 
31,290 
11,538 


1,200 
2,078 
2,405 
1,404 


7,709 

14,194 

4,974 

4,729 


8,550 
9,236 
9,683 
2,801 


21,147 

23,959 

12,262 

9,983 


2,677 
4,851 


Fixed charges — interest and principal 
— depreciation 


4,196 

2,377 


















283,541 


26,405 


102,512 


114,143 


157,980 


50,316 






Net income or net expense 


6,533 


2,509 


3,503 


24,740 


19,478 


8,586 


Number of customers 


1,927 


201 


953 


959 


1,299 


668 



Statements A and B 
Statements for the Year Ended December 31, 1960 



217 



Dryden 
5.740 


Espanola 
5,068 


Fort 
William 
43.968 


Hearst 
2,102 


Kapuskas- 

ing 

6,444 


Larder 

Lake Twp. 

1,990 


Latchford 
437 


Masse y 
1.325 


McGarry 
2,944 


$ 
515,124 
95,843 


$ 
258,282 
43,872 


$ 
3,963.205 
759,937 


$ 
214.523 
28,176 


$ 
388,733 
16,939 


% 

63,778 
23,068 


$ 

31,549 
6,167 


$ 

82.386 
6,257 


$ 

72,570 
16,651 


419.281 
42 


214,410 
22.011 


3,203,268 

295,183 
85,500 
113,678 


186.347 

23.506 

40,000 

7,771 


371,794 
1,188 


40,710 
13,337 


25,382 
5,800 


76,129 
6,468 


55,919 
9.607 


3.343 


18,678 


2,430 


724 


2,935 


1,373 


437 


3,385 
11,941 


40,689 


494,361 
126,420 


71,277 


3,618 

7,727 


14,061 


8,735 


7,841 


10.044 
















266 


5.468 


11.844 


4,867 


13,872 


2,259 




2,717 


231 








12,207 


5,468 


138,264 
4,550.221 


4,867 


21,599 
3,556 


2,259 

878 




2.717 


231 


60.776 


113 


849 












495,649 


260,567 


8,386,114 


262,491 


400,567 


57,908 


34,230 


86,687 


67,043 


65,503 


145,000 
19,542 

7,773 


508.000 
110,074 
87,496 


59,100 

1,406 

10,624 


37,462 
17.174 
9.682 


5,900 
1,553 
6,211 




36.500 

215 

1.658 


5,000 


38,003 
18,862 


44 
365 


13 
5,467 


122,368 
60,776 


172,315 


705,570 

4,550.221 
2,909 


71,130 


64,318 

3,556 
518 


13,664 

878 
135 


409 

113 
39 


38,373 


10,480 
849 


454 




467 














61,230 




4,553,130 
556,209 


467 
80,900 


4,074 
53.017 


1,013 
12,100 


152 
18,901 




849 


60,927 




8,500 


9,000 








251,124 


88,252 


2,571,205 


109,994 


279,158 


31,131 


14,768 


39,814 


46,714 




















312,051 


88,252 


3,127,414 


190,894 


332,175 


43,231 


33.669 


48,314 


55,714 


495,649 


260,567 


8,386,114 


262,491 


400,567 


57,908 


34,230 


86,687 


67,043 


207,715 
5,770 


43,169 
192 


1,697,212 
31,733 


86,615 
1,400 


205,943 
3.443 


52,054 
91 


10.509 


42,659 


55,859 
46 










213,485 


43,361 


1,728,945 


88,015 


209,386 


52,145 


10,509 


42,659 


55,905 


117,013 


26,354 


1,098,990 


61,920 


129.673 


36,624 


7.296 


19,060 


37,680 


34,065 
25,357 
10,114 


2,199 
5,247 
3,231 
1,663 


163,716 
128,690 
49,385 
98,007 


6,115 
7,157 
8,600 
3,919 


14,893 

27,840 

6,474 

7,661 


3,828 
5,231 
1,562 
2,104 


553 
938 


7,580 
6,903 
3,886 

1,782 


3.149 

7.052 
1,240 


12,011 


846 


2,014 
















198,560 


38,694 


1,538,788 


87,711 


186,541 


49,349 


9,633 


39,211 


51,135 


14,925 


4,667 


190,157 


304 


22,845 


2,796 


876 


3,448 


4,770 


1,691 


1,289 


13,719 


719 


2,015 


561 


155 


356 


480 



218 



Municipal Electrical Service 



Northern Ontario Properties- 



Municipal Electrical Utilities Financial 
Concluded 





Nipigon 
Twp. 

2,700 


North Bay 
23,010 


Port Arthur 
42,581 


Rainy River 
1,198 


Red Rock 
1,740 






Twp. 
2 165 






A. BALANCE SHEETS 

FIXED ASSETS 


$ 
161,097 
27,071 


$ 
1,716,546 
383,931 


$ 
4,752,047 
1,544,095 


$ 

81,806 
41,739 


$ 

98,172 
19,742 


$ 
135,003 




21,531 








134,026 

17,184 

15,000 

1,316 


1.332,615 
27,764 


3,207,952 

116,823 
247,000 
173,128 


40,067 
24,222 


78,430 
19,460 


113 472 


CURRENT ASSETS 


10,678 




24,890 




26,786 


6,068 


697 


1,176 








33.500 


54,550 
35,576 


536,951 
217,093 


30,290 
1,714 


20,157 
1.738 


36 744 


OTHER ASSETS 












7,732 


3,987 




1,833 
















43,308 
14,385 


221,080 
8,345,047 


1,714 


3,571 
33,570 




Equity in Ontario Hydro Systems. . . . 


90,016 


41,821 










257,542 


1,444,858 


12,311,030 


72,071 


135,728 


192,037 


LIABILITIES 




348,000 
44,572 
76,837 




8,000 
106 
300 


13,130 

48 
170 






443 

2,757 


162,113 


46 


Other 












3,200 
90,016 


469,409 

14,385 
2,118 


162,113 

8,345,047 
109,882 


8,406 


13,348 
33,570 


46 


RESERVES 

Equity in Ontario Hydro Systems. . 
Other 


41,821 


519 














90,016 
10,000 


16,503 
312,158 


8,454,929 
626,317 


519 
18,087 


33,570 
18,070 


41,821 


CAPITAL 


50,000 






Accumulated net income invested in 
plant or held as working funds. 
Frequency standardization expense 


154,326 


646,788 


3,067,671 


45,059 


70,740 


100,170 


















164,326 


958,946 


3,693,988 


63,146 


88,810 


150,170 








257,542 


1,444,858 


12,311,030 


72,071 


135,728 


192,037 


B. OPERATING STATEMENTS 

REVENUE 
Sales of electric energy 


71,901 
3,081 


909,260 
4,387 


1,777,331 
45,753 


61,375 
1,721 


37,710 
310 


54,878 


Other 


1,220 






Total revenue 


74,982 


913,647 


1,823,084 


63,096 


38,020 


56,098 






EXPENSE 


49,658 


529,722 


1,246,147 

19,419 

174,281 

149,820 


27,318 


25,127 


33,672 






Operation and maintenance 


9,443 
8,208 


95,236 
113,939 
34,130 
45,628 


9,595 
8,797 
4,330 
3,096 


1,961 
3,710 
2,196 
2.547 


5,250 
8,374 


Fixed charges — interest and principal 
— depreciation 




3,861 


83,998 


3,275 


















71,170 


818,655 


1,673,665 


53,136 


35,541 


50,571 






Net income or net expense 


3,812 


94,992 


149,419 


9,960 


2,479 


5,527 


Number of customers 


731 


7,499 


13,673 


452 


331 


647 



Statements A and B 
Statements for the Year Ended December 31, 1960 



219 



Sioux 
Lookout 

2,645 


Sturgeon 
Falls 

6,288 


Sudbury 
77,356 


Terrace 
Bay 

1,900 


Thessalon 
1,717 


Webbwood 
590 


West Ferris 
Twp. 

5,096 


Total 

Northern 

Ontario 

Properties 


Total 
All Systems 


$ 

214,735 
27,136 


$ 
335.476 
44,248 


$ 
5,517,019 
836,782 


$ 
178,484 
38,154 


$ 
116,966 
23,226 


$ 

39.132 
2,482 


$ 
530,163 
37,499 


$ 
20,877,246 
4,238,264 


$ 

413.611,989 

82,246,973 


187,599 

10,726 
5,000 


291,228 

150 

15.255 


4,680,237 

175,619 

75,150 

200,684 


140,330 

29,945 

65,000 

763 


93.740 
2,409 


36,650 
2,055 


492,664 
18.507 


16,638,982 

967,684 
619,344 
627,734 


331,365,016 

12,250.801 
13.990,120 


6,369 


4.518 


1,074 


6.363 


12.868.807 


22,095 
6,459 


15,405 
3,932 


451,453 
83,986 


95,708 


6.927 


3.129 


24.870 
2.089 


2,214,762 
509,199 


39.109,728 
9,197,511 










2,316,958 




30.428 




3.412 


1.623 


8.945 


139,332 


2,553,588 








6,459 


3,932 
2,338 


114,414 




3,412 
702 


1.623 


11.034 


648,531 
13,275,646 


14,068.057 




68,704 


261,101,650 












216,153 


312,903 


5,246,104 


304,742 


104,781 


41,402 


528,568 


32,777,921 


645,644,451 


4,400 


98,500 
24,310 
10,535 


634,044 
759,539 
139,284 


39,000 


54,000 
1.938 
1,489 


24,312 
251 
291 


319,500 

4.112 

25,917 


3,074,651 

1,217,729 

478,377 


74,429,684 
10,485,382 


6,647 




7,146,524 








11,047 


133,345 

2,338 
526 


1,532,867 


39,000 
68,704 


57,427 
702 


24,854 


349,529 


4.770,757 

13,275.646 
136,414 


92,061,590 
261,101,650 




17,051 


74 


507 


2,920,005 












2,864 
21,500 

155,194 


17,051 
866,882 


68,704 
39,000 


702 
11,000 


74 
5,689 


507 
48,000 


13.412,060 
3,012,557 


264,021,655 

81,266,027 
2,316,958 


205,106 


2,829,304 


158,038 


35,652 


10,785 


130,532 


11,582,547 


205,984,657 
6,436 


















205,106 


176.694 


3.696.186 


197,038 


46,652 


16,474 


178,532 


14,595,104 


289,561,206 


216,153 


312,903 


5,246,104 


304,742 


104,781 


41,402 


528,568 


32,777,921 


645,644,451 


131,414 
1,031 


147,625 
448 


2,444,115 
40.639 


58,249 
3,227 


59,769 
142 


18,324 


219,402 
6,386 


9,169,608 
161,680 


186.599,701 
2,720,870 








132,445 


148,073 


2,484,754 


61,476 


59,911 


18,324 


225,788 


9,331,288 


189,320,571 


81,882 


91,923 

14,409 

21,292 

10,571 

7.901 


1.336.528 


38,483 


28.664 


6.123 


125,881 


5,650,433 
19,419 
971,221 
903.170 
392.316 
444.473 


122.634.361 
536,118 


12.926 
16,768 

4,961 


324.952 
226,171 
149,611 
107,183 


2,913 
5,121 
5,498 
4,733 


4,245 

12,703 

5,065 

2.992 


4,511 

2,677 

2.628 

826 


19,211 
24,805 
28,985 
10,633 


18,273,164 

15,766.246 

7,440.556 

10,750,710 

22,506 


















116,537 


146,096 


2,144,445 


56,748 


53,669 


16,765 


209,515 


8,381,032 


175,423,661 


15,908 


1,977 


340,309 


4,728 


6,242 


1,559 


16,273 


950,256 


13,896,910 


943 


1.613 


22.216 


428 


534 


155 


1.835 


78.049 


1,351,915 



220 Municipal Electrical Service 



INTRODUCTION TO STATEMENT "C" AND STATEMENT "D" 

STATEMENT "C" 

Statement "C" is the schedule of resale rates for residential, commercial, 
and industrial power service in the municipal distribution systems receiving power 
from the Commission. From time to time as revision becomes necessary, these 
rates are adjusted to the rate structures first introduced in 1956. 



Description of Classes of Service 

Residential rates are applicable to all electrical service for household purposes, 
with the exception of house heating and flat-rate water-heaters. Charges for 
normal residential service are based on specified blocks of kilowatt-hours per 
month with suitable rates for each block. The account is subject to a minimum 
monthly charge and to a prompt payment discount of 10 per cent. For com- 
parative purposes, net monthly bills are shown for metered energy consumptions 
of 100, 300, and 500 kilowatt-hours per month. 

The water-heater rates shown in Statement "C" are for unmetered flat-rate 
service which is billed at a monthly rate per 100 watts of heater capacity. In 
many municipalities the flat-rate water-heater load is subject to peak-load 
control by the utility. The customer, of course, has the option of paying for 
water heating at regular rates through the regular metered service. House- 
heating rates quoted are for separately metered consumption where an area 
greater than 25 per cent of the total is heated by electricity. 

Commercial rates are applicable to all electrical service supplied to stores, 
offices, churches, schools, public buildings, institutions, hospitals, hotels, restau- 
rants, service stations, and other premises used for commercial purposes. The 
commercial rates are also used for billing sign and display lighting. In most 
municipalities on the new rate structures, commercial-type customers having 
connected loads of less than five kilowatts are billed at residential rates. Rates 
for industrial power service to customers of the municipal systems provide for 
24-hour unrestricted delivery at secondary distribution voltage. These rates, 
however, are not applicable to the Commission's direct industrial customers. 

Commercial and industrial power service accounts consist of a monthly 
demand rate (with a minimum for commercial service) applied to the customer's 
billing demand, plus energy charges for specified blocks of kilowatt-hours used, 
the size of the blocks varying in accordance with the customer's billing demand. 
All additional energy is billed at the end rate per kilowatt-hour. Under the 1956 
rate structures the two specified blocks for industrial power service are twice as 
large as those under the former structures. The accounts are subject to a 
prompt payment discount of 10 per cent. Industrial power service customers 
providing their own step-down transformation are granted, on the basis of their 



Introduction to Statements C and D 221 

billing demand, an allowance of 270 per kilowatt per month gross for service 
at subtransmission voltage and 1 70 per kilowatt per month gross for service at 
primary distribution voltage. The net monthly bills shown for commercial and 
industrial power service are calculated on the basis of a demand of one kilowatt 
for a use per month of 100, 200, and 300 hours. The corresponding bill for a 
demand of 10 kilowatts would be ten times the amounts shown, for 20 kilowatts 
twenty times the amounts shown, and so on. 



STATEMENT "D" 

Statement "D" records revenue, consumption, number of customers, 
average consumption per customer, and average cost per kilowatt-hour for each 
of the three main classes of service in all the municipal systems served. The 
revenue and consumption from house heating and the use of flat-rate water- 
heaters are included in the totals shown, the flat-rate water-heater kilowatt- 
hours being estimated on the basis of 16.8 hours' use per day. 

When a municipal utility adopts the 1956 rate structures, a substantial 
number of commercial service customers having small connected loads (under 
5 kilowatts) may be transferred to residential service billing, and certain small 
industrial power service customers may be reclassified under commercial service. 
In order to correct distortions in the calculation of average consumption per 
customer that would result from these changes, estimated averages are sub- 
stituted for the arithmetic averages in the year the changes are made. 

The average cost per kilowatt-hour shown is the average cost to the customer, 
that is the average revenue per kilowatt-hour received by the utility. Such a 
statistical average does not represent the utility's actual cost of delivering one 
kilowatt-hour. However, a comparison of this average over a number of years 
is some indication of the trend of cost in any one municipality, and the trend 
in all municipal systems combined may be seen in the table on page 164 and the 
graphs on page 165. Other things being equal, the average cost per kilowatt- 
hour would rise with an increase in rates. Consumption per customer, however, 
is continuously increasing, and residential customers in particular are using an 
ever-increasing variety of electrical appliances, including flat-rate water-heaters. 
This increased use, since it is billed at the low rates usually applicable to higher- 
consumption blocks of kilowatt-hours, is frequently reflected in a lower average 
cost per kilowatt-hour. 

For industrial power service customers, the relationship between demand 
(kilowatts required) and energy (kilowatt-hours of use) is an important factor in 
establishing the customer's average cost per kilowatt-hour. The use of the 
demand for only a few hours will result in a relatively small total bill but a high 
average cost per kilowatt-hour; the use of the same demand for several hours will 
increase the total bill but substantially reduce the average cost per kilowatt-hour. 
In other words, the average cost per kilowatt-hour varies inversely with the 
customer's load factor. 



222 



Municipal Electrical Service 



Municipal Electrical 
RATES AND TYPICAL BILLS 

in effect 

Rates are quoted on a monthly basis and 
and a minimum 



Municipality 



rt o 



Residential service 



a 
a 

it 

I" 5 
E 



Rate per kwh 
for 






XJ3 



.J. * 

•3-* 



Net monthly bill 
for 



Acton 

Ailsa Craig. 

Ajax 

Alexandria . 
Alfred 



Alliston 

Almonte 

Alvinston 

Amherstburg 

Ancaster Twp. (including 
Ancaster) 



Apple Hill. 
Arkona. . . 
Arn prior. . 
Arthur. . . . 
Athens. . . . 



Atikokan Twp. 

Aurora 

Avonmore 

Aylmer 

Ayr 



Baden 

fBala 

Bancroft. . . 

Barrie 

Barry's Bay. 



Bath 

Beachville . 

Beamsville. 

fBeardmore. 

Beaverton . 



Beeton 

Belle River. 

Belleville. . . 

Blenheim. . . 

t Blind River. 

Bloomfield. . 

Blyth 

Bobcaygeon . 

Bolton 

Bothwell. . . 



i No. 

45 

45 
37 
40 
42 



43 



43 



44 



35 



37 



i 

1.67 
1.67 
1.67 
1.67 
1.67 

1.67 
1.67 
1.67 
1.67 



1.67 
1.67 
1.67 
1.67 

1.67 
1.67 
1.67 
1.67 



1.67 
1.67 
1.67 
1.67 
1.67 

1.67 
1.67 
1.67 
1.67 
1.67 

1.67 
1.67 
1.67 
1.67 
1.67 

1.67 
1.67 
1.67 
1.78 
1.67 



No. 
50 
50 
50 
50 
50 

60 
50 
60 
50 

60 

60 
50 
50 
50 
50 

50 
50 
50 
50 
60 

50 
50 
60 
60 
50 

60 
50 
60 
50 
60 

50 
50 
60 
50 
50 

50 
50 
60 
50 
60 



I 

3.0 

3.0 

3.4 

2.4 

3.2 

3.1 
2.4 
3.5 
3.0 

4.2 

4.0 
3.2 
2.4 
2.8 
2.0 

3.2 
3.0 
4.0 
2.2 
2.9 

2.8 
4.4 
3.5 
2.4 
2.6 

3.5 

2.8 
2.7 
4.0 
2.8 

3.2 
3.6 
1.8 
3.0 
3.8 

2.0 
2.8 
3.4 
3.6 
2.6 



i 

1.5 
1.5 
1.7 
1.2 
1.6 



1.2 
1.5 



1.6 
1.2 
1.4 
1.0 

1.6 
1.5 
2.0 
1.1 



1.4 
2.2 



1.3 

1.4 
2.0 



1.6 
1.8 



1.0 
1.4 



1.8 



i 

0.9 

0.8 
1.0 
0.7 
0.9 



0.7 
0.8 



1.0 

0.7 
0.8 
0.7 

1.0 
0.8 
1.1 
0.7 



0.8 
1.2 



0.7 

0.8 
1.2 

0.9 



0.7 
0.8 



t 

1.2 

1.2 

1.4 

1.0 

1.3 

1.0 
1.0 
1.0 
1.2 



1.0 
1.4 
1.0 
1.1 
1.0 

1.4 
1.2 
1.6 
1.0 
1.0 

1.1 
1.6 
1.3 
1.0 
1.0 

1.2 
1.1 
1.2 
1.6 
1.2 

1.3 
1.5 
0.8 
0.9 
1.5 

1.0 
1.1 
1.2 
1.5 
1.0 



$ 
2.02 
2.02 
2.29 
1.62 
2.16 

2.03 
1.62 

2.25 
2.02 

2.70 

2.52 
2.16 
1.62 
1.89 
1.35 

2.16 
2.02 
2.70 
1.48 
1.93 

1.89 
2.97 
2.36 
1.66 
1.75 

2.32 
1.89 
1.89 
2.70 
1.94 

2.16 
2.43 
1.26 
2.02 
2.56 

1.35 
1.89 
2.27 
2.43 
1.76 



$ 
4.45 
4,41 
5.04 
3.55 
4.72 

3,83 
3.55 
4.05 
4.41 

4.86 

4.32 
4.77 
3.55 
4.14 
3.01 

4.77 
4.41 
5.89 
3.28 
3.73 

4.14 
6.48 
4.70 
3.46 
3.82 

4.48 
4.14 
4.05 
5.94 
4.10 

4.72 
5.35 
2.70 
4.45 
5.62 

3.01 
4.14 
4.43 
5.35 
3.56 



fLocal system 
For explanatory notes and water-heating schedules see pages 240 to 243. 



Statement C 



223 



Utilities and Local Systems 
FOR ELECTRICAL SERVICE 
December 31, 1960 

are subject to 10% prompt payment discount 
monthly charge 



Commercial service 


Industrial power service 


Demand rate 
per 100 watts 






















5.0 cents, 
minimum 50 cents 


Net monthly bill 

for use of 
1 kw of demand 


a 




Energy rate per kwh 

for use of 
each kw of demand 




Net monthly 

for use o 

1 kw of dem 


bill 

f 


Energy rate per 


and 


kwh for use of 
each kw of demand 








c 
E 

Q 














00 

3 
O 


CO 

t- 

3 
O 

II 


CO 

u 

3 

cfl g 

§•2 


CO 

3 
O 

si 
o 
o 


3 
O 

-C 

o 
o 
cs 


CO 

3 
O 
JO 

o 
o 

C5 


2 

3 
toJS 

• r -o 


CO 

3 
O 

£2 


co 

3 

*-> o 

£° 


co 

O 


CO 
Ih 

3 
.X. o 

•3 a 


CO 

3 
O 
JC 

o 

o 


co 
In 

3 
O 

o 
o 


3 
O 

A 

O 
O 
**> 


t 


i 


i 


$ 


$ 


$ 


$ 


t 


i 


i 


i 


i 


$ 


$ 


$ 


°2.6. 


0.8 


0.5 


2.79 


3.51 


3.96 


1.00 




2.1 




0.5 


0.33 


2.79 


3.24 


3.54 


°2.7 


0.8 


0.5 


2.88 


3.60 


4.05 


1.00 




2.1 




0.5 


0.33 


2.79 


3.24 


3.54 


°2.5 


0.8 


0.5 


2.70 


3.42 


3.87 


1.00 




1.8 




0.5 


0.33 


2.52 


2.97 


3.27 


°2.3 


0.8 


0.5 


2.52 


3.24 


3.69 


1.00 




1.8 




0.5 


0.33 


2.52 


2.97 


3.27 


°2.6 


0.8 


0.5 


2.79 


3.51 


3.96 


1.00 




2.0 




0.5 


0.33 


2.70 


3.15 


3.45 


2.6 




1.0 


2.79 


3.69 


4.59 


1.20 


1.9 




1.3 




0.30 


2.52 


2.79 


3.06 


°1.9 


0.8 


0.5 


2.16 


2.88 


3.33 


1.00 




1.1 




0.5 


0.33 


1.89 


2.34 


2.64 


3.0 




0.9 


3.15 


3.96 


4.77 


1.35 


2.8 




1.8 




0.33 


3.28 


3.58 


3.88 


°2.8 


0.8 


0.5 


2.97 


3.69 


4.14 


1.00 




2.2 




0.5 


0.33 


2.88 


3.33 


3.63 


3.6 




1.0 


3.69 


4.59 


5.49 


1.35 


2.9 




1.9 




0.33 


3.37 


3.67 


3.97 


3.5 




1.0 


3.60 


4.50 


5.40 


1.35 


2.8 




1.8 




0.33 


3.28 


3.58 


3.88 


°2.9 


0.8 


0.5 


3.06 


3.78 


4.23 


1.00 




2.4 




0.5 


0.33 


3.06 


3.51 


3.81 


°1.9 


0.8 


0.5 


2.16 


2.88 


3.33 


1.00 




1.4 




0.5 


0.33 


2.16 


2.61 


2.91 


°2.5 


0.8 


0.5 


2.70 


3.42 


3.87 


1.00 




1.8 




0.5 


0.33 


2.52 


2.97 


3.27 


•1.5 


0.8 


0.5 


1.80 


2.52 


2.97 


1.00 




1.0 




0.5 


0.33 


1.80 


2.25 


2.55 


°3.0 


0.8 


0.5 


3.15 


3.87 


4.32 


1.00 




2.0 




0.5 


0.33 


2.70 


3.15 


3.45 


°2.6 


0.8 


0.5 


2.79 


3.51 


3.96 


1.00 




2.1 




0.5 


0.33 


2.79 


3.24 


3.54 


°3.0 


0.8 


0.5 


3.15 


3.87 


4.32 


1.00 




2.0 




0.5 


0.33 


2.70 


3.15 


3.45 


°1.9 


0.8 


0.5 


2.16 


2.88 


3.33 


1.00 




1.4 




0.5 


0.33 


2.16 


2.61 


2.91 


2.4 




0.9 


2.61 


3.42 


4.23 


1.20 


2.1 




1.4 




0.30 


2.65 


2.92 


3.19 


°2.3 


0.8 


0.5 


2.52 


3.24 


3.69 


1.00 




1-7 




0.5 


0.33 


2.43 


2.88 


3.18 


°4.2 


0.8 


0.5 


4.23 


4.95 


5.40 


1.00 




2.7 




0.5 


0.33 


3.33 


3.78 


4.08 


3.0 




1.2 


3.15 


4.23 


5.31 


1.20 


2.1 




1.4 




0.30 


2.65 


2.92 


3.19 


2.0 




0.8 


2.25 


2.97 


3.69 


1.00 


1.4 




0.9 




0.25 


1.93 


2.16 


2.38 


°1.9 


0.8 


0.5 


2.16 


2.88 


3.33 


1.00 




1.4 




0.5 


0.33 


2.16 


2.61 


2.91 


3.0 




1.2 


3.15 


4.23 


5.31 


1.35 


3.5 




2.3 




0.33 


3.82 


4.12 


4.42 


°2.4 


0.8 


0.5 


2.61 


3.33 


3.78 


1.00 




1.9 




0.5 


0.33 


2.61 


3.06 


3.36 


2.3 




1.1 


2.52 


3.51 


4.50 


1.20 


1.9 




1.3 




0.30 


2.52 


2.79 


3.06 


°3.8 


0.8 


0.5 


3.87 


4.59 


5.04 


1.00 




2.9 




0.5 


0.33 


3.51 


3.96 


4.26 


2.2 




1.0 


2.43 


3.33 


4.23 


1.35 


2.0 




1.3 




0.33 


2.70 


3.00 


3.29 


°2.8 


0.8 


0.5 


2.97 


3.69 


4.14 


1.00 




2.3 




0.5 


0.33 


2.97 


3.42 


3.72 


°3.0 


0.8 


0.5 


3.15 


3.87 


4.32 


1.00 




2.2 




0.5 


0.33 


2.88 


3.33 


3.63 


1.6 




0.6 


1.89 


2.43 


2.97 


1.00 


1.3 




0.8 




0.25 


1.84 


2.07 


2.29 


°2.7 


0.8 


0.5 


2.88 


3.60 


4.05 


1.00 




2.2 




0.5 


0.33 


2.88 


3.33 


3.63 


°3.6 


0.8 


0.5 


3.69 


4.41 


4.86 


1.00 




2.7 




0.5 


0.33 


3.33 


3.78 


4.08 


1.8 


0.8 


0.5 


2.07 


2.79 


3.24 


1.00 




1.3 




0.5 


0.33 


2.07 


2.52 


2.82 


°2.5 


0.8 


0.5 


2.70 


3.42 


3.87 


1.00 




2.0 




0.5 


0.33 


2.70 


3.15 


3.45 


2.9 




1.0 


3.06 


3.96 


4.86 


1.35 


2.3 




1.5 




0.33 


2.92 


3.22 


3.52 


°3.0 


0.8 


0.5 


3.15 


3.87 


4.32 


1.00 




2.1 




0.5 


0.33 


2.79 


3.24 


3.54 


2.1 




0.7 


2.34 


2.97 


3.60 


1.35 


2.3 




1.5 




0.33 


2.92 


3.22 


3.52 



224 



Municipal Electrical Service 



Municipal Electrical 
RATES AND TYPICAL BILLS 

in effect 

Rates are quoted on a monthly basis and 
and a minimum 









Residential service 


Municipality 


c 
rt o 

2* 


i- 
Jg 

E 

3 
C 

a 

3 


J* 
u 

& 

M 

C 

4> 

J3 
U 

10 

3 
O 

X 

■ 


T3 

.a 

"S 

a 

3J* 

E 

3 


Rate per kwh 
for 


Net 


monthly bill 
for 




E ° 


u 

o 


o 
o 


o 
o 

B| 


Si 

•3-* 


is 

o 
o 


X, 

■s 

M 

8 

<*5 


J3 

■s 

§ 


Bowmanville 


i No. 
35 
39 
40 

36 
37 

41 
42 

45 

40 
45 

39 

38 

45 
43 
43 

45 
42 
43 

43 

35 

50 

48 

43 
40 
39 

41 

42 

38 

41 

46 

41 
41 

40 

45 

41 
42 
33 
41 

35 


i 

1.67 
1.67 
1.67 
1.67 
1.67 

1.67 

2.0 

1.67 

1.67 

1.67 

1.67 
1.67 
1.67 
1.67 
1.67 

1.67 
1.67 
1.67 

1.67 

1.67 

1.67 
1.67 

1.67 

1.67 

1.67 

1.67 
1.67 
1.67 

1.67 

1.67 
1.67 
1.67 
1.67 


No. 
50 
60 
50 
50 
50 

60 
50 
50 
50 
50 

50 
60 
60 
50 
60 

50 
50 
50 
60 
50 

60 
60 
60 
50 
50 

50 
50 
50 
60 
60 

50 
60 
60 
60 
50 

50 
50 
50 
50 
60 


i 

2.4 
3.0 
2.8 
2.6 
3.2 

2.2 
4.0 
2.6 
3.0 
2.6 

2.6 
2.0 
3.2 
3.4 
4.0 

3.4 
4.0 
3.6 
2.4 
2.0 

3.0 
3.2 
3.5 
2.6 
3.2 

3.4 
2.8 
2.6 
9.0 
3.8 

2.8 
2.7 
2.7 
3.1 
3.0 

3.0 
4.0 
1.6 
3.0 
3.4 


i 

1.2 

1.4 
1.3 
1.6 

2.0 
1.3 
1.5 
1.3 

1.3 

1.7 

1.7 
2.0 
1.8 

1.0 

1.3 
1.6 

1.7 
1.4 
1.3 

1.4 

1.5 

1.5 
2.0 
0.8 
1.5 


0.7 
0.8 
1.0 

1.2 
0.7 
0.9 
0.7 

0.7 

1.0 

1.0 
1.2 
1.1 

0.7 

0.8 
1.0 

1.0 
0.8 
0.8 

0.8 

0.9 

0.9 
1.1 
0.5 
0.8 


i 

1.0 
1.2 
1.1 
1.1 
1.4 

1.2 
1.6 
1.0 
1.2 
1.0 

1.0 
1.0 
1.0 
1.4 
1.0 

1.4 
1.6 
1.5 
1.2 
1.0 

1.3 
1.0 
1.3 
1.1 
1.4 

1.4 
1.1 
1.1 
4.0 
1.4 

1.1 
1.0 
1.1 
1.4 

1.2 

1.2 
1.6 
1.0 
1.2 
1.5 


$ 

1.62 
2.05 
1.89 
1.75 
2.16 

1.62 
2.70 
1.75 
2.02 
1.75 

1.75 
1.44 
2.09 
2.29 
2.52 

2.29 
2.70 
2.43 
1.73 
1.35 

2.09 
2.09 
2.36 
1.75 
2.16 

2.29 
1.89 
1.75 
6.30 
2.56 

1.89 
1.82 
1.85 
2.18 
2.02 

2.02 
2.70 
1.08 
2.02 
2.38 


$ 

3.55 
4.21 
4.14 
4.00 
4.77 

3.78 
5.94 
3.82 
4.45 
3.82 

3.82 
3.24 
3.89 
5.04 
4.32 

5.04 
5.94 
5.35 
3.89 
3.01 

4.43 
3.89 
4.70 
3.87 
4.77 

5.04 
4.14 
3.87 
13.50 
5.08 

4.14 
3.62 
3.83 
4.70 
4.45 

4.45 
5.89 
2.38 
4.41 
5.08 


$ 

4.81 


Bracebridge 


6.37 


Bradford 


5.58 


Braeside 


5.98 




6.57 


Brantford 


5.94 


§§Brantford Twp 


8.10 


Brechin 


5.08 


Bridgeport 


6.07 


Brigden 


5.08 


Brighton. . . . 


5.08 


Brockville 


5.04 


Brussels 


5.69 


Burford 


6.84 


Burgessville. . 


6.12 


Burk's Falls 


6.84 


§Burlington 


8.10 


Cache Bay. . . 


7.33 


Caledonia 


6.05 


Campbellford 


4.27 


Campbellville 


6.77 


Cannington 


5.69 


Capreol 


7.04 


Cardinal 


5.31 


Carleton Place 


6.57 


Casselman 


6.84 


Cayuga 


5.58 


Chalk River 


5.31 


Chapleau Twp 


20.70 


Chatham 


7.60 


Chatsworth 


5.58 


Chesley 


5.42 


Chesterville 


5.81 




7.22 


Clifford 


6.07 


Clinton 


6.07 


tCobalt 


7.87 


Cobden 


3.28 


Cobourg 


5.85 


Cochrane 


7.78 



tLocal system 
For explanatory notes and water-heating schedules see pages 240 to 243. 



, 



Statement C 



225 



Utilities and Local Systems 
FOR ELECTRICAL SERVICE 
December 31, 1960 

are subject to 10% prompt payment discount 
monthly charge 



Commercial service 


Industrial power service 


Demand rate 
per 100 watts 






















5.0 cents, 
minimum 50 cents 


Net monthly bill 

for use of 
1 kw of demand 


* 

.* 

£ 




Energy rate per kwh 

for use of 
each kw of demand 




Net monthly 

for use o 

1 kw of dem 


bill 


Energy rate per 


and 


kwh for use of 
each kw of demand 








3 

E 
u 















& 

3 
O 

!§ 


co 

3 
O 

ll 


co 

.J 

•3-e 
9 g 


CO 

C 

3 
O 

© 
o 


co 

3 
O 

8 

tN 


3 
O 

8 


2 

3 

is 


<o 

3 

Is 


co 

3 
*J O 

X.3 

4. to 


to 
V* 

3 
O 

11 


co 
3 


CO 

13 

3 
O 

X! 
O 

o 


2 

3 
O 
.3. 

8 


CO 

3 

O 

§ 


i 


i 


i 


$ 


$ 


$ 


$ 


i 


i 


i 


i 


i 


$ 


$ 


$ 


°1.7 


0.8 


0.5 


1.98 


2.70 


3.15 


1.00 




1.2 




0.5 


0.33 


1.98 


2.43 


2.73 


2.0 




1.0 


2.25 


3.15 


4.05 


1.20 


1.4 




0.9 




0.30 


2.11 


2.38 


2.65 


°2.6 


0.8 


0.5 


2.79 


3.51 


3.96 


1.00 




1.8 




0.5 


0.33 


2.52 


2.97 


3.27 


°2.2 


0.8 


0.5 


2.43 


3.15 


3.60 


1.00 




1.7 




0.5 


0.33 


2.43 


2.88 


3.18 


°2.5 


0.8 


0.5 


2.70 


3.42 


3.87 


1.00 




1.9 




0.5 


0.33 


2.61 


3.06 


3.36 


1.8 




0.7 


2.07 


2.70 


3.33 


1.20 


1.4 




0.9 




0.30 


2.11 


2.38 


2.65 


°2.9 


0.8 


0.5 


3.06 


3.78 


4.23 


1.00 




2.2 




0.5 


0.33 


2.88 


3.33 


3.63 


°2.6 


0.8 


0.5 


2.79 


3.51 


3.96 


1.00 




1.4 




0.5 


0.33 


2.16 


2.61 


2.91 


°2.5 


0.8 


0.5 


2.70 


3.42 


3.87 


1.00 




1.6 




0.5 


0.33 


2.34 


2.79 


3.09 


°2.5 


0.8 


0.5 


2.70 


3.42 


3.87 


1.00 




2.0 




0.5 


0.33 


2.70 


3.15 


3.45 


°2.3 


0.8 


0.5 


2.52 


3.24 


3.69 


1.00 




1.5 




0.5 


0.33 


2.25 


2.70 


3.00 


1.7 




0.8 


1.98 


2.70 


3.42 


1.20 


1.4 




0.9 




0.30 


2.11 


2.38 


2.65 


2.7 




0.8 


2.88 


3.60 


4.32 


1.35 


2.8 




1.8 




0.33 


3.28 


3.58 


3.88 


°2.9 


0.8 


0.5 


3.06 


3.78 


4.23 


1.00 




2.1 




0.5 


0.33 


2.79 


3.24 


3.54 


3.5 




0.8 


3.60 


4.32 


5.04 


1.35 


2.9 




1.9 




0.33 


3.37 


3.67 


3.97 


°2.8 


0.8 


0.5 


2.97 


3.69 


4.14 


1.00 




2.3 




0.5 


0.33 


2.97 


3.42 


3.72 


°2.9 


0.8 


0.5 


3.06 


3.78 


4.23 


1.00 




2.2 




0.5 


0.33 


2.88 


3.33 


3.63 


°3.5 


0.8 


0.5 


3.60 


4.32 


4.77 


1.00 




3.0 




0.5 


0.33 


3.60 


4.05 


4.35 


1.9 




1.1 


2.16 


3.15 


4.14 


1.35 


2.3 




1.5 




0.33 


2.92 


3.22 


3.52 


°1.2 


0.8 


0.5 


1.53 


2.25 


2.70 


1.00 




0.7 




0.5 


0.33 


1.53 


1.98 


2.28 


2.8 




1.1 


2.97 


3.96 


4.95 


1.35 


3.5 




2.3 




0.33 


3.82 


4.12 


4.42 


2.8 




0.9 


2.97 


3.78 


4.59 


1.35 


2.2 




1.4 




0.33 


2.83 


3.13 


3.43 


3.0 




1.1 


3.15 


4.14 


5.13 


1.35 


2.9 




1.9 




0.33 


3.37 


3.67 


3.97 


°2.3 


0.8 


0.5 


2.52 


3.24 


3.69 


1.00 




1.8 




0.5 


0.33 


2.52 


2.97 


3.27 


°2.8 


0.8 


0.5 


2.97 


3.69 


4.14 


1.00 




1.8 




0.5 


0.33 


2.52 


2.97 


3.27 


°2.9 


0.8 


0.5 


3.06 


3.78 


4.23 


1.00 




2.2 




0.5 


0.33 


2.88 


3.33 


3.63 


°2.6 


0.8 


0.5 


2.79 


3.51 


3.96 


1.00 




2.1 




0.5 


0.33 


2.79 


3.24 


3.54 


°2.1 


0.8 


0.5 


2.34 


3.06 


3.51 


1.00 




1.4 




0.5 


0.33 


2.16 


2.61 


2.91 


8.5 




4.0 


8.10 


11.70 


15.30 


1.35 


5.7 




3.8 




2.00 


5.49 


7.29 


9.09 


3.3 




1.2 


3.42 


4.50 


5.58 


1.35 


2.0 




1.3 




0.40 


2.70 


3.00 


3.29 


°2.5 


0.8 


0.5 


2.70 


3.42 


3.87 


1.00 




2.0 




0.5 


0.33 


2.70 


3.15 


3.45 


2.3 




1.0 


2.52 


3.42 


4.32 


1.20 


1.9 




1.3 




0.30 


2.52 


2.79 


3.06 


2.2 




1.1 


2.43 


3.42 


4.41 


1.35 


2.0 




1.3 




0.33 


2.70 


3.00 


3.29 


2.6 




1.3 


2.79 


3.96 


5.13 


1.20 


1.9 




1.3 




0.30 


2.52 


2.79 


3.06 


°2.7 


0.8 


0.5 


2.88 


3.60 


4.05 


1.00 




2.2 




0.5 


0.33 


2.88 


3.33 


3.63 


°2.6 


0.8 


0.5 


2.79 


3.51 


3.96 


1.00 




2.0 




0.5 


0.33 


2.70 


3.15 


3.45 


°3.6 


08 


0.5 


3.69 


4.41 


4.86 


1.00 




2.4 




0.5 


0.33 


3.06 


3.51 


3.81 


°1.3 


0.8 


0.5 


1.62 


2.34 


2.79 


1.00 




0.8 




0.5 


0.33 


1.62 


2.07 


2.37 


°2.4 


0.8 


0.5 


2.61 


3.33 


3.78 


1.00 




1.6 




0.5 


0.33 


2.34 


2.79 


3.09 


2.9 




1.4 


3.06 


4.32 


5.58 


1.35 


2.3 




1.5 




0.33 


2.92 


3.22 


3.52 



226 



Municipal Electrical Service 



Municipal Electrical 
RATES AND TYPICAL BILLS 

in effect 

Rates are quoted on a monthly basis and 
and a minimum 



Municipality 



M u 






l J 




8 2 g 


M 


-c t> 


T 


i_, 


it 


C 


a 


fg 


* 

3 


bt 


4) u 


■a 


Ctf 
4) 




co 

3 


C* ° 


O 




K 






■ 



Residential service 



a. 

a 

co o 



Rate per kwh 
for 



8 



•3-* 

a) 2 



Net monthly bill 
for 



Colborne . . . 
Coldwater. . 
Collingwood . 
Comber. . . . 

Coniston. . . 



Cookstown , 
Cottam. . . 
Court right. 
Creemore . . 
Dashwood . 



Deep River. 
Delaware . . . 

Delhi 

Deseronto. . 
Dorchester. 



Drayton. 
Dresden . 
Drumbo. 
Dryden . 
Dublin. . 



Dundalk. . 
Dundas. . 
Dunnville . 
Durham. . 
Dutton. . . 



East York Twp 

Eganville 

fElk Lake Townsite. 

Elmira 

Elmvale 



Elmwood . 
Elora. . . . 
Embro. . . 
fEnglehart. 
Erieau . . . 



Erie Beach 

Erin 

Espanola 

Essex 

Etobicoke Twp. 
(including Thistletown) 



i No. 


i 


43 


1.67 


40 


1.67 


41 


1.67 


45 


1.67 


42 


1.67 


45 


1.67 


41 




43 




44 


1.67 


45 




40 


1.67 


44 


1.67 


43 


1.80 


40 


1.67 


43 


1.67 


44 


1.67 


44 


1.67 


45 


1.67 


35 


1.67 


43 


1.67 


44 


1.67 


40 


1.67 


45 


1.78 


42 


1.67 


47 


1.67 


37 


1.67 


42 


1.67 


42 


1.67 


45 


1.67 


40 


1.67 


39 


1.67 


44 


1.67 


44 


1.67 


42 


1.67 


45 


1.67 


45 


1.67 


40 


1.67 


40 


1.67 


43 


1.67 


40 


1.67 



No. 
60 
50 
50 
50 
50 

50 
50 
50 
50 
50 

50 
60 
50 
50 
50 

50 
50 
50 
50 
50 

50 
60 
60 
60 
50 

50 
60 
50 
50 
50 

50 
60 
60 
50 
50 

50 
50 
50 
50 



i 

3.8 
2.6 
2.4 
3.0 
3.2 

2.6 
2.8 
2.4 
3.1 
3.6 

3.4 
3.8 
2.6 
2.6 
2.8 

3.4 
3.0 
2.8 
3.8 
2.8 

2.8 
2.8 
2.6 

2.7 
2.8 

2.6 
4.3 
3.6 
3.0 
2.6 

2.6 
3.2 
3.3 
4.0 
2.8 

4.0 
3.0 
3.8 
3.0 

4.0 



1.3 
1.2 
1.5 
1.6 

1.3 
1.4 
1.2 



1.3 
1.3 
1.4 

1.7 
1.5 
1.4 
1.9 
1.4 



1.4 

1.3 

1.8 
1.5 
1.3 

1.3 



2.0 
1.4 

2.0 
1.5 
1.9 
1.5 



0.7 
0.7 
0.9 
1.0 

0.8 
0.8 
0.7 

1.1 

1.0 

0.8 
0.7 
0.8 

1.0 
0.9 
0.8 
1.1 
0.8 

0.8 



0.8 
0.8 

1.1 

0.8 
0.8 

0.7 



0.8 
1.1 
0.8 



i 

1.0 
1.0 
1.0 
1.2 
1.4 

1.1 
1.1 
1.0 
1.0 
1.5 

1.4 

1.4 
1.1 
1.0 
1.1 

1.4 
1.2 
1.1 
1.5 
1.1 

1.1 
1.1 
1.5 
1.1 
1.1 

1.1 
1.1 
1.5 
1.2 
1.1 

1.0 
1.4 
1.1 
1.6 
0.8 

1.1 
1.2 
1.5 
1.2 



$ 
2.41 
1.75 
1.62 
2.02 
2.16 

1.75 
1.89 
1.62 
1.84 
2.43 

2.29 
2.56 
1.75 
1.75 
1.89 

2.29 
2.02 
1.89 
2.56 
1.89 

1.89 
1.91 
1.94 
1.85 
1.89 

1.75 
2.72 
2.43 
2.02 
1.75 

1.75 
2.23 
2.18 
2.70 
1.89 

2.70 
2.02 
2.56 
2.02 

2.63 



$ 
4.21 
3.82 
3.55 
4.45 
4.77 

3.87 
4.14 
3.55 
3.64 
5.35 

5.04 
5.08 
3.87 
3.82 
4.14 

5.04 
4.45 
4.14 
5.62 
4.14 

4.14 
3.89 
4.64 
3.83 
4.14 

3.87 
4.70 
5.35 
4.41 
3.87 

3.82 
4.75 
4.16 
5.89 
4.14 

5.89 
4.41 
5.62 
4.41 

4.97 



fLocal system 

For explanatory notes and water-heating schedules see pages 240 to 243. 



Statement C 



227 



Utilities and Local Systems 
FOR ELECTRICAL SERVICE 
December 31, 1960 

are subject to 10% prompt payment discount 
monthly charge 



Commercial service 


Industrial power service 


Demand rate 
per 100 watts 




















5.0 cents, 
minimum 50 cents 


Net monthly bill 

for use of 
1 kw of demand 


<v 
a. 

u. 

C 

B 

Q 


Energy rate per kwh 

for use of 
each kw of demand 




Net monthly 

for use of 

1 kw of dem? 


bill 


Energy rate per 

kwh for use of 

each lew of demand 


md 


to 

3 
O 

!§ 


CO 

3 
O 

II 


3 

35 


to 

3 
O 

Si 
© 

o 


3 
O 

JS 

o 
o 


3 
O 

Si 

o 
o 


CO 

a 

£8 


n 

3 
O 

II 


3 
** O 

£° 


3 
O 

11 


3. 


to 

3 
O 

JS 

o 
o 


h 

3 


o 
o 

CN 


to 

a 

3 
O 

A 

o 
o 

V) 


3.0 


t 


(5 
1.0 


3.15 


$ 

4.05 


$ 

4.95 


$ 
1.35 


2.8 


i 


i 

1.8 


i 


0.33 


$ 

3.28 


$ 

3.58 


$ 

3.88 


°2.1 


0.8 


0.5 


2.34 


3.06 


3.51 


1.00 




1.6 




0.5 


0.33 


2.34 


2.79 


3.09 


°1.9 


0.8 


0.5 


2.16 


2.88 


3.33 


1.00 




1.3 




0.5 


0.33 


2.07 


2.52 


2.82 


°2.7 


0.8 


0.5 


2.88 


3.60 


4.05 


1.00 




2.2 




0.5 


0.33 


2.88 


3.33 


3.63 


°2.7 


0.8 


0.5 


2.88 


3.60 


4.05 


1.00 




2.0 




0.5 


0.33 


2.70 


3.15 


3.45 


°2.4 


0.8 


0.5 


2.61 


3.33 


3.78 


1.00 




1.7 




0.5 


0.33 


2.43 


2.88 


3.18 


°2.8 


0.8 


0.5 


2.97 


3.69 


4.14 


1.00 




2.3 




0.5 


0.33 


2.97 


3.42 


3.72 


°2.l 


0.8 


0.5 


2.34 


3.06 


3.51 


1.00 




1.6 




0.5 


0.33 


2.34 


2.79 


3.09 


2.6 




0.9 


2.79 


3.60 


4.41 


1.20 


1.6 




1.0 




0.30 


2.25 


2.52 


2.79 


°3.1 


0.8 


0.5 


3.24 


3.96 


4.41 


1.00 




2.4 




0.5 


0.33 


3.06 


3.51 


3.81 


°2.9 


0.8 


0.5 


3.06 


3.78 


4.23 


1.00 




2.2 




0.5 


0.33 


2.88 


3.33 


3.63 


3.4 




1.4 


3.51 


4.77 


6.03 


1.35 


3.1 




2.0 




0.33 


3.51 


3.81 


4.10 


°2.4 


0.8 


0.5 


2.61 


3.33 


3.78 


1.00 




1.8 




0.5 


0.33 


2.52 


2.97 


3.27 


°2.2 


0.8 


0.5 


2.43 


3.15 


3.60 


1.00 




1.6 




0.5 


0.33 


2.34 


2.79 


3.09 


°2.6 


0.8 


0.5 


2.79 


3.51 


3.96 


1.00 




2.1 




0.5 


0.33 


2.79 


3.24 


3.54 


°2.9 


0.8 


0.5 


3.06 


3.78 


4.23 


1.00 




2.2 




0.5 


0.33 


2.88 


3.33 


3.63 


°2.8 


0.8 


0.5 


2.97 


3.69 


4.14 


1.00 




2.3 




0.5 


0.33 


2.97 


3.42 


3.72 


°2.7 


0.8 


0.5 


2.88 


3.60 


4.05 


1.00 




2.2 




0.5 


0.33 


2.88 


3.33 


3.63 


°3.1 


0.8 


0.5 


3.24 


3.96 


4.41 


1.00 




2.4 




0.5 


0.33 


3.06 


3.51 


3.81 


°2.7 


0.8 


0.5 


2.88 


3.60 


4.05 


1.00 




2.6 




0.5 


0.33 


3.24 


3.69 


3.99 


"2.3 


0.8 


0.5 


2.52 


3.24 


3.69 


1.00 




1.7 




0.5 


0.33 


2.43 


2.88 


3.18 


2.3 




1.0 


2.52 


3.42 


4.32 


1.20 


1.6 




1.0 




0.30 


2.25 


2.52 


2.79 


2.2 




1.5 


2.43 


3.78 


5.13 


1.35 


2.3 




1.5 




0.33 


2.92 


3.22 


3.52 


2.4 




1.0 


2.61 


3.51 


4.41 


1.35 


2.2 




1.4 




0.33 


2.83 


3.13 


3.43 


°2.5 


0.8 


0.5 


2.70 


3.42 


3.87 


1.00 




2.0 




0.5 


0.33 


2.70 


3.15 


3.45 


°2.0 


0.8 


0.5 


2.25 


2.97 


3.42 


1.00 




1.3 




0.5 


0.33 


2.07 


2.52 


2.82 


3.8 




1.0 


3.87 


4.77 


5.67 


1.35 


2.5 




1.6 




0.33 


3.06 


3.36 


3.65 


°3.0 


0.8 


0.5 


3.15 


3.87 


4.32 


1.00 




2.4 




0.5 


0.33 


3.06 


3.51 


3.81 


°2.8 


0.8 


0.5 


2.97 


3.69 


4.14 


1.00 




1.9 




0.5 


0.33 


2.61 


3.06 


3.36 


°2 t 


0.8 


0.5 


2.34 


3.06 


3.51 


1.00 




1.6 




0.5 


0.33 


2.34 


2.79 


3.09 


°2.3 


0.8 


0.5 


2.52 


3.24 


3.69 


1.00 




1.8 




0.5 


0.33 


2.52 


2.97 


3.27 


2.8 




1.4 


2.97 


4.23 


5.49 


1.35 


2.0 




1.3 




0.33 


2.70 


3.00 


3.29 


2.7 




0.7 


2.88 


3.51 


4.14 


1.35 


3.1 




2.0 




0.33 


3.51 


3.81 


4.10 


°3.6 


0.8 


0.5 


3.69 


4.41 


4.86 


1.00 




2.4 




0.5 


0.33 


3.06 


3.51 


3.81 


°2.8 


0.8 


0.5 


2.97 


3.69 


4.14 


1.00 




2.5 




0.5 


0.33 


3.15 


3.60 


3.90 


°3.5 


0.8 


0.5 


3.60 


4.32 


4.77 


1.00 




2.6 




0.5 


0.33 


3.24 


3.69 


3.99 


°2.5 


0.8 


0.5 


2.70 


3.42 


3.87 


1.00 




1.7 




0.5 


0.33 


2.43 


2.88 


3.18 


°2.8 


0.8 


0.5 


2.97 


3.69 


4.14 


1.00 




1.8 




0.5 


0.33 


2.52 


2.97 


3.27 


°2.7 


0.8 


0.5 


2.88 


3.60 


4.05 


1.00 




2.0 




0.5 


0.33 


2.70 


3.15 


3.45 


°2.4 


0.8 


0.5 


2.61 


3.33 


3.78 


1.00 




1.7 




0.5 


0.33 


2.43 


2.88 


3.18 



228 



Municipal Electrical Service 



Municipal Electrical 
RATES AND TYPICAL BILLS 

in effect 

Rates are quoted on a monthly basis and 
and a minimum 



Municipality 



4) 09 

2& 



Residential service 



a 

a 

0> O 



Rate per kwh 
for 









J, * 



Net monthly bill 
for 



JS 
M 


8 

1*5 


$ 


4.43 


4.59 


3.55 


3.01 


4.43 


3.55 


4.41 


2.81 


3.87 


4.00 


4.45 


4.72 


5.94 


3.55 


4.41 


10.17 


5.62 


4.21 


5.13 


3.01 


3.73 


4.45 


3.89 


5.89 


3.78 


3.35 


4.45 


4.45 


3.55 


4.45 


5.04 


6.79 


3.89 


5.35 


4.10 


3.67 


3.78 


8.64 


6.48 


3.89 


4.64 



Exeter 
Fergus 

Finch 

Flesherton . 
Fonthill . . . 



1 


No. 


i 




45 


1.67 




41 


1.67 


42 






37 




1.67 




41 


1.67 



Forest 

Forest Hill . . 
Fort William . 
Frankford. . . 
Gait 



Georgetown .... 

Glen Williams. 

fGeraldton 

Glencoe 

Goderich 

fGogama 



Grand Bend. 
Grand Valley. 

Granton 

Gravenhurst . 
Grimsby. . . . 



Guelph 

Hagersville . 

fHaileybury. 

Hamilton. . 

Hanover. . . 



Harriston. . . 
Harrow. . . . 
Hastings. . . 
Havelock. . . 
Hawkesbury 



Hearst . . . 
Hensall . . . 
fHepworth . 
Hespeler. . 
Highgate . 



Holstein 

tHornepayne 

fHudson Townsite 

Huntsville 

Ingersoll 



36 



1.67 
1.67 
1.67 
1.67 
1.67 

1.67 
1.67 
1.67 
1.67 
1.67 
1.67 

1.78 
1.67 

1.67 
1.67 

1.67 
1.67 
1.67 
1.67 
1.67 

1.67 
1.67 
1.67 
1.67 
1.67 

1.67 
1.67 
1.67 
1.67 
1.67 

1.67 

1.67 
1.67 
1.67 



No. 
60 
60 
50 
50 
60 

50 
50 
60 
50 
60 

50 
50 
50 
50 
50 
50 

60 
60 
60 
50 
60 

50 
60 
50 
60 
60 

50 
50 
50 
50 
50 

50 
60 
50 
60 
60 

60 
60 
50 
60 
60 



i 

3.0 
3.3 
2.4 
2.0 
3.0 

2.4 
3.0 
2.0 
2.6 
3.0 

3.0 
3.2 
4.0 
2.4 
3.0 
7.0 

4.4 
3.0 
3.9 
2.0 

2.5 

3.0 
2.8 
4.0 
2.6 
2.2 

3.0 
3.0 
2.4 
3.0 
3.4 

4.6 

3.2 
3.6 
3.2 
3.2 

3.0 
8.0 
4.4 
2.4 
3.4 



1.2 
1.0 



1.2 
1.5 



1.3 



1.5 
1.6 
2.0 
1.2 
1.5 
3.5 



1.0 

1.5 
2.0 



1.5 
1.5 
1.2 
1.5 
1.7 

2.3 

1.8 



0.7 
0.7 



0.7 
0.8 



0.8 



0.9 
0.9 
1.2 
0.7 
0.8 



0.7 

0.9 
1.1 



0.9 
0.9 
0.7 
0.9 
1.0 

1.3 



i 

1.3 
1.3 
1.0 
1.0 
1.3 

1.0 
1.2 
0.8 
1.1 
1.1 

1.2 
1.3 
1.6 
1.0 
1.2 
1.6 

1.5 
1.2 
1.4 
1.0 
1.1 

1.2 
1.1 
1.6 
1.1 
1.0 

1.2 
1.2 
1.0 
1.2 
1.4 

1.6 
1.0 
1.5 
1.1 
0.9 

1.0 
2.0 
1.6 
1.2 
1.3 



$ 
2.09 
2.25 
1.62 
1.35 
2.09 

1.62 
2.02 
1.37 
1.75 
2.02 

2.02 
2.16 
2.70 
1.62 
2.02 
4.72 

2.92 
2.05 
2.61 
1.35 
1.75 

2.02 
1.91 
2.70 
1.80 
1.55 

2.02 
2.02 
1.62 
2.02 
2.29 

3.10 
2.09 
2.43 
2.12 
2.05 

1.98 
5.04 
2.97 
1.73 
2.30 



fLocal system 

For explanatory notes and water-heating schedules see pages 240 to 243. 



Statement C 



229 



Utilities and Local Systems 
FOR ELECTRICAL SERVICE 
December 31, 1960 

are subject to 10% prompt payment discount 
monthly charge 



Commercial service 


Industrial power service 


Demand rate 
per 100 watts 






















5.0 cents, 
minimum 50 cents 


Net 
1 k 


monthly bill 
for use of 
w of demand 


u 

a 

V 

rt 
i_ 

T3 

a 
rt 
E 
u 
Q 




Energy rate per kwh 

for use of 
each kw of demand 




Net monthly bill 

for use of 
1 kw of demand 


Energy rate per 

kwh for use of 

each kw of demand 


CO 


co 

u 
3 

A 

£g 


CO 

j, 8 


CO 

3 
O 

O 
O 


CO 

3 
O 

JS 

o 
o 

CN 


3 
O 

-C 

o 
o 


co 

u 

3 

+> o 

r<= 


co 

a 

3 
O 


CO 
In 

3 

IS 


CO 

U 

3 
O 

II 


CO 

3 
.J. o 

•3-c 
«ig 


CO 

3 
O 

•G 

§ 


CO 

3 
O 

JS 

o 
o 


CO 

3 
O 

§ 

<*5 


i 


i 


if 


$ 


$ 


$ 


$ 


i 


i 


t 


i 


i 


$ 


$ 


$ 


2.6 




0.8 


2.79 


3.51 


4.23 


1.20 


2.1 




1.4 




0.30 


2.65 


2.92 


3.19 


2.8 




1.1 


2.97 


3.96 


4.95 


1.35 


2.2 




1.4 




0.33 


2.83 


3.13 


3.43 


°2.1 


0.8 


0.5 


2.34 


3.06 


3.51 


1.00 




1.6 




0.5 


0.33 


2.34 


2.79 


3.09 


°1.6 


0.8 


0.5 


1.89 


2.61 


3.06 


1.00 




1.0 




0.5 


0.33 


1.80 


2.25 


2.55 


2.5 




1.2 


2.70 


3.78 


4.86 


1.35 


2.5 




1.6 




0.33 


3.06 


3.36 


3.65 


°2.2 


0.8 


0.5 


2.43 


3.15 


3.60 


1.00 




1.6 




0.5 


0.33 


2.34 


2.79 


3.09 


°1.8 


0.8 


0.5 


2.07 


2.79 


3.24 


1.00 




1.3 




0.5 


0.33 


2.07 


2.52 


2.82 


1.9 




0.4 


2.16 


2.52 


2.88 


1.00 


1.4 




0.9 




0.25 


1.93 


2.16 


2.38 


°1.8 


0.8 


0.5 


2.07 


2.79 


3.24 


1.00 




1.1 




0.5 


0.33 


1.89 


2.34 


2.64 


2.5 




1.0 


2.70 


3.60 


4.50 


1.20 


1.6 




1.0 




0.30 


2.25 


2.52 


2.79 


°2.4 


0.8 


0.5 


2.61 


3.33 


3.78 


1.00 




1.7 




0.5 


0.33 


2.43 


2.88 


3.18 


°2.6 


0.8 


0.5 


2.79 


3.51 


3.96 


1.00 




2.0 




0.5 


0.33 


2.70 


3.15 


3.45 


°3.8 


0.8 


0.5 


3.87 


4.59 


5.04 


1.00 




2.9 




0.5 


0.33 


3.51 


3.96 


4.26- 


°2.4 


0.8 


0.5 


2.61 


3.33 


3.78 


1.00 




1.9 




0.5 


0.33 


2.61 


3.06 


3.36 


°2.5 


0.8 


0.5 


2.70 


3.42 


3.87 


1.00 




2.0 




0.5 


0.33 


2.70 


3.15 


3.45 


5.8 


0.8 


0.5 


5.67 


6.39 


6.84 


1.00 




5.1 




0.5 


0.33 


5.49 


5.94 


6.24 


3.9 




1.3 


3.96 


5.13 


6.30 


1.35 


3.1 




2.0 




0.33 


3.51 


3.81 


4.10 


2.5 




1.2 


2.70 


3.78 


4.86 


1.20 


2.1 




1.4 




0.30 


2.65 


2.92 


3.19 


3.4 




1.3 


3.51 


4.68 


5.85 


1.35 


2.6 




1.7 




0.33 


3.15 


3.45 


3.74 


°1.6 


0.8 


0.5 


1.89 


2.61 


3.06 


1.00 




1.1 




0.5 


0.33 


1.89 


2.34 


2.64 


2.0 




1.0 


2.25 


3.15 


4.05 


1.20 


1.7 




1.2 




0.30 


2.38 


2.65 


2.92 


°2.2 


0.8 


0.5 


2.43 


3.15 


3.60 


1.00 




1.5 




0.5 


0.33 


2.25 


2.70 


3.00 


2.3 




0.9 


2.52 


3.33 


4.14 


1.20 


1.7 




1.2 




0.30 


2.38 


2.65 


2.92 


°3.6 


0.8 


0.5 


3.69 


4.41 


4.86 


1.00 




2.4 




0.5 


0.33 


3.06 


3.51 


3.81 


cl.9 




0.7 


2.16 


2.79 


3.42 


1.00 


1.4 




0.9 




0.40 


1.93 


2.29 


2.65 


1.7 




1.0 


1.98 


2.88 


3.78 


1.00 


1.5 




0.9 




0.30 


1.98 


2.25 


2.52 


°2.8 


0.8 


0.5 


2.97 


3.69 


4.14 


1.00 




2.1 




0.5 


0.33 


2.79 


3.24 


3.54 


°2.7 


0.8 


0.5 


2.88 


3.60 


4.05 


1.00 




2.0 




0.5 


0.33 


2.70 


3.15 


3.45 


°2.0 


0.8 


0.5 


2.25 


2.97 


3.42 


1.00 




1.5 




0.5 


0.33 


2.25 


2.70 


3.00 


°2.5 


0.8 


0.5 


2.70 


3.42 


3.87 


1.00 




1.7 




0.5 


0.33 


2.43 


2.88 


3.18 


u 3.2 


0.8 


0.5 


3.33 


4.05 


4.50 


1.00 




1.7 




0.5 


0.33 


2.43 


2.88 


3.18 


°3.9 


0.8 


0.5 


3.96 


4.68 


5.13 


1.00 




3.2 




0.5 


0.33 


3.78 


4.23 


4.53 


2.7 




0.9 


2.88 


3.69 


4.50 


1.20 


2.1 




1.4 




0.30 


2.65 


2.92 


3.19 


°3.2 


0.8 


0.5 


3.33 


4.05 


4.50 


1.00 




2.4 




0.5 


0.33 


3.06 


3.51 


3.81 


2.6 




0.9 


2.79 


3.60 


4.41 


1.20 


1.6 




1.0 




0.33 


2.25 


2.55 


2.84 


2.8 




0.7 


2.97 


3.60 


4.23 


1.35 


2.6 




1.7 




0.33 


3.15 


3.45 


3.74 


2.5 




0.8 


2.70 


3.42 


4.14 


1.35 


3.5 




2.3 




0.33 


3.82 


4.12 


4.42 


7.5 




2.0 


7.20 


9.00 


10.80 


1.35 


4.9 




3.3 




0.33 


4.90 


5.20 


5.50 


°3.9 


0.8 


0.5 


3.96 


4.68 


5.13 


1.00 




3.4 




0.5 


0.33 


3.96 


4.41 


4.71 


2.2 


... 


1.1 


2.43 


3.42 


4.41 


1.20 


1.6 




1.0 




0.30 


2.25 


2.52 


2.79 


2.8 


... ' 


0.8 


2.97 


3.69 


4.41 


1.20 


1.9 




1.3 




0.30 


2.52 


2.79 


3.06 



230 



Municipal Electrical Service 



Municipal Electrical 
RATES AND TYPICAL BILLS 

in effect 

Rates are quoted on a monthly basis and 
and a minimum 



Municipality 



C 


u 






X 


•d 


2 tn 

X £ 

a, £ 

cd o 


E 

9 
C 

0> 


8 

a 

M 

c 


a 
a 

O) o 

X° 


£© 


9 


£-° 




1 


G 

x 




rt 


T. 


01 

3 


XI 


Ex, 




O 

X 


E 

3 






■ 


z 



Residential service 



Rate per kwh 
for 



xx 

ti,"o 



o 


o 


© 


o 




l/> 






*X 


xx 


£ £ 


£. £ 


£j* 


£J5 



35 




Net monthly bill 
for 



Iroquois 

Jarvis 

tjellicoe Townsite. 

Kapuskasing 

tKearns Townsite. 



Kemptville 

Kincardine 

tKing Kirkland Townsite 

Kingston , 

Kingsville 



Kirkfield 

tKirkland Lake (including 

Swastika) 

Kitchener 

Lakefield 

Lambeth 



Lanark 

Lancaster 

Larder Lake T\ 

Latchford 

Leamington. . . 



Lindsay 

Listowel 

London 

London Twp. 
Long Branch 



L'Orignal. 
Lucan. . . 
Lucknow. 
Lynden . . 
Madoc . . . 



Magnetawan. 
Markdale. . . 
Markham . . 
Marmora. . . . 
Martintown . 



Massey 

tMatachewan Twp. 

tMatheson 

tMattawa 

Maxville 



i 


No. 


i 


No. 


i 


i 


i 




40 


1.67 


60 


2.8 








45 


1.67 


50 


3.2 


1.6 


0.9 




45 


1.67 


50 


4.4 


2.2 


1.2 




35 




50 


3.0 


1.5 


0.9 




45 


1.67 


50 


3.6 


1.8 


1.1 




40 


1.67 


50 


2.6 


1.3 


0.7 


45 




1.67 


50 


2.4 


1.2 


0.7 




42 


1.67 


50 


3.6 


1.8 


1.1 


38 




1.67 


60 


1.8 






40 




1.67 


50 


2.4 


1.2 


0.7 




45 


1.67 


50 


3.2 


1.6 


1.0 




42 


1.67 


50 


3.6 


1.8 


1.1 




39 


1.67 


60 


2.6 








34 


1.67 


55 


2.8 








43 


1.67 


60 


3.5 








39 


1.67 


50 


2.2 


1.1 


0.7 




39 


1.67 


50 


2.4 


1.2 


0.7 




43 




60 


3.5 






44 






50 


3.0 


1.5 


0.8 




41 


1.67 


50 


2.8 


1.4 


0.8 


41 




1.67 


50 


2.6 


1.3 


0.8 




41 


1.67 


50 


2.8 


1.4 


0.8 




38 


1.67 


60 


2.8 






39 






50 


3.2 


1.6 


1.0 




41 


1.67 


60 


3.1 








40 


1.67 


50 


3.8 


1.9 


1.1 




45 


1.67 


50 


3.2 


1.6 


1.0 




45 


1.67 


55 


2.7 








43 


1.67 


50 


3.0 


1.5 


0.8 




40 


1.67 


50 


2.4 


1.2 


0.7 




45 


1.67 


50 


4.2 


2.1 


1.2 


45 




1.67 


60 


2.5 








44 


1.67 


50 


3.2 


1.6 


1.0 




43 


1.67 


60 


3.6 








38 


1.67 


50 


2.8 


1.4 


0.8 




45 




50 


5.0 


2.5 


1.4 




45 


1.67 


50 


3.6 


1.8 


1.1 




45 


1.67 


50 


3.4 


1.7 


1.0 




45 


1.67 


50 


5.2 


2.6 






43 


1.67 


50 


2.6 


1.3 


0.8 



t 

1.2 
1.3 
1.6 
1.2 
1.5 

1.0 
1.0 
1.5 
0.9 
1.0 



1.5 
1.3 
1.0 
1.3 

1.0 
1.0 
1.1 
1.2 
1.1 

1.1 
1.1 
1.2 
1.4 
1.2 

1.5 
1.4 
1.0 
1.2 
1.0 

1.6 
1.0 
1.4 
1.0 
1.1 

1.6 
1.5 
1.4 
1.6 
1.1 



$ 
1.94 
2.16 
2.97 
2.02 
2.43 

1.75 
1.62 
2.43 
1.30 
1.62 

2.16 

2.43 
1.87 
1.79 
2.36 

1.48 
1.62 
2.29 
2.02 
1.89 

1.75 
1.89 
1.94 
2.16 
2.11 

2.56 
2.16 
1.75 
2.02 
1.62 

2.83 
1.71 
2.16 
2.30 
1.89 

3.37 
2.43 
2.29 
3.51 
1.75 



$ 
4.10 
4.72 
6.48 
4.45 
5.35 

3.82 
3.55 
5.35 
2.92 
3.55 

4.77 

5.35 
4.21 
3.59 
4.70 

3.28 
3.55 
4.27 
4.41 
4.14 

3.87 
4.14 
4.10 
4.77 
4.27 

5.62 
4.77 
3.55 
4.41 
3.55 

6.21 
3.51 
4.77 
4.10 
4.14 

7.38 
5.35 
5.04 
7.74 
3.87 



tLocal system 
For explanatory notes and water-heating schedules see pages 240 to 243. 



Statement C 



231 



Utilities and Local Systems 
FOR ELECTRICAL SERVICE 
December 31, 1960 

are subject to 10% prompt payment discount 
monthly charge 



Commercial service 


Industrial power service 


Demand rate 

per 100 watts 

5.0 cents, 

minimum 50 cents 


Net monthly bill 

for use of 
1 kw of demand 


tJ 

a 




Energy rate per kwh 

for use of 
each kw of demand 




Net monthl 

for use ( 

1 kw of der 


y bill 
)f 


Energy rate per 


nand 


kwh for use of 
each kw of demand 








g 

■d 

C 

■ 
E 

p 














2 

3 
O 

h 


co 

3 


z2 


to 

3 
.A O 

•3-c 

5-2 


co 

3 
O 

JC 

8 


co 

3 
O 

£ 

8 


CO 

3 
O 
,C 

o 
o 
*) 


3 

E8 


CO 

3 
O 

uO 

£2 


an 

3 
-H ° 

£° 


CO 

3 
O 

II 


CO 

3 
.A o 


co 

u 

§ 

8 


co 
C 

3 
O 

8 


CO 

1 

8 


i 


* 


* 


$ 


$ 


$ 


$ 


i 


t 


i 


i 


i 


$ 


$ 


$ 


2.3 




1.0 


2.52 


3.42 


4.32 


1.35 


2.0 




1.3 




0.33 


2.70 


3.00 


3.29 


°2.8 


0.8 


0.5 


2.97 


3.69 


4.14 


1.00 




2.3 




0.5 


0.33 


2.97 


3.42 


3.72 


°3.9 


0.8 


0.5 


3.96 


4.68 


5.13 


1.00 




3.4 




0.5 


0.33 


3.96 


4.41 


4.71 


°2.7 


0.8 


0.5 


2.88 


3.60 


4.05 


1.00 




2.0 




0.5 


0.33 


2.70 


3.15 


3.45 


°3.0 


0.8 


0.5 


3.15 


3.87 


4.32 


1.00 




2.4 




0.5 


0.33 


3.06 


3.51 


3.81 


°2.3 


0.8 


0.5 


2.52 


3.24 


3.69 


1.00 




1.7 




0.5 


0.33 


2.43 


2.88 


3.18 


°2.4 


0.8 


0.5 


2.61 


3.33 


3.78 


1.00 




1.9 




0.5 


0.33 


2.61 


3.06 


3.36 


°3.0 


0.8 


0.5 


3.15 


3.87 


4.32 


1.00 




2.4 




0.5 


0.33 


3.06 


3.51 


3.81 


1.5 




0.9 


1.80 


2.61 


3.42 


1.20 


1.4 




0.9 




0.30 


2.11 


2.38 


2.65 


°2.2 


0.8 


0.5 


2.43 


3.15 


3.60 


1.00 




1.7 




0.5 


0.33 


2.43 


2.88 


3.18 


°3.0 


0.8 


0.5 


3.15 


3.87 


4.32 


1.00 




2.4 




0.5 


0.33 


3.06 


3.51 


3.81 


°3.0 


0.8 


0.5 


3.15 


3.87 


4.32 


1.00 




2.4 




0.5 


0.33 


3.06 


3.51 


3.81 


2.3 




1.0 


2.52 


3.42 


4.32 


1.20 


2.1 




1.4 




0.30 


2.65 


2.92 


3.19 


2.4 




0.8 


2.61 


3.33 


4.05 


1.20 


1.7 




1.2 




0.30 


2.38 


2.65 


2.92 


3.1 




1.1 


3.24 


4.23 


5.22 


1.35 


4.1 




2.7 




0.33 


4.27 


4.57 


4.87 


°1.9 


0.8 


0.5 


2.16 


2.88 


3.33 


1.00 




1.4 




0.5 


0.33 


2.16 


2.61 


2.91 


°2.0 


0.8 


0.5 


2.25 


2.97 


3.42 


1.00 




1.5 




0.5 


0.33 


2.25 


2.70 


3.00 


3.0 




1.0 


3.15 


4.05 


4.95 


1.35 


3.1 




2.0 




0.33 


3.51 


3.81 


4.10 


°2.5 


0.8 


0.5 


2.70 


3.42 


3.87 


1.00 




1.7 




0.5 


0.33 


2.43 


2.88 


3.18 


°2.5 


0.8 


0.5 


2.70 


3.42 


3.87 


1.00 




2.0 




0.5 


0.33 


2.70 


3.15 


3.45 


°2.2 


0.8 


0.5 


2.43 


3.15 


3.60 


1.00 




1.5 




0.5 


0.33 


2.25 


2.70 


3.00 


°2.4 


0.8 


0.5 


2.61 


3.33 


3.78 


1.00 




1.8 




0.5 


0.33 


2.52 


2.97 


3.27 


2.2 




0.6 


2.43 


2.97 


3.51 


1.20 


1.4 




0.9 




0.30 


2.11 


2.38 


2.65 


°2.7 


0.8 


0.5 


2.88 


3.60 


4.05 


1.00 




1.9 




0.5 


0.33 


2.61 


3.06 


3.36 


°2.3 


0.8 


0.5 


2.52 


3.24 


3.69 


1.00 




1.7 




0.5 


0.33 


2.43 


2.88 


3.18 


°2.5 


0.8 


0.5 


2.70 


3.42 


3.87 


1.00 




1.7 




0.5 


0.33 


2.43 


2.88 


3.18 


°2.7 


0.8 


0.5 


2.88 


3.60 


4.05 


1.00 




2.0 




0.5 


0.33 


2.70 


3.15 


3.45 


2.2 




0.8 


2.43 


3.15 


3.87 


1.35 


2.8 




1.8 




0.33 


3.28 


3.58 


3.88 


°2 * 


0.8 


0.5 


2.79 


3.51 


3.96 


1.00 




2.0 




0.5 


0.33 


2.70 


3.15 


3.45 


°2.3 


0.8 


0.5 


2.52 


3.24 


3.69 


1.00 




1.8 




0.5 


0.33 


2.52 


2.97 


3.27 


°3.7 


0.8 


0.5 


3.78 


4.50 


4.95 


1.00 




2.8 




0.5 


0.33 


3.42 


3.87 


4.17 


2.0 




1.0 


2.25 


3.15 


4.05 


1.20 


1.9 




1.3 




0.30 


2.52 


2.79 


3.06 


°2.7 


0.8 


0.5 


2.88 


3.60 


4.05 


1.00 




2.1 




0.5 


0.33 


2.79 


3.24 


3.54 


3.2 




0.9 


3.33 


4.14 


4.95 


1.35 


2.3 




1.5 




0.33 


2.92 


3.22 


3.52 


°2.3 


0.8 


0.5 


2.52 


3.24 


3.69 


1.00 




1.7 




0.5 


0.33 


2.43 


2.88 


3.18 


°4.4 


0.8 


0.5 


4.41 


5.13 


5.58 


1.00 




3.1 




0.5 


0.33 


3.69 


4.14 


4.44 


°3.0 


0.8 


0.5 


3.15 


3.87 


4.32 


1.00 




2.4 




0.5 


0.33 


3.06 


3.51 


3.81 


"3.3 


0.8 


0.5 


3.42 


4.14 


4.59 


1.00 




2.4 




0.5 


0.33 


3.06 


3.51 


3.81 


5.2 


0.8 


0.5 


5.13 


5.85 


6.30 


1.00 




3.2 




0.5 


0.33 


3.78 


4.23 


4.53 


°2.6 


0.8 


0.5 


2.79 


3.51 


3.96 


1.00 




2.1 




0.5 


0.33 


2.79 


3.24 


3.54 



232 



Municipal Electrical Service 



Municipal Electrical 
RATES AND TYPICAL BILLS 

in effect 

Rates are quoted on a monthly basis and 
and a minimum 



Municipality 





ha 

0/ 




si 




£ 
5 

3 
C 


& 
^ 




a 


cd o 


« 


bt 


£© 


3 




** u 


1 


CO 

.c 


2& 


A 

* 


^ 


u 


cfl 


ka 


3 


to 




O 

■ 



Residential service 



a 
a 

CO CJ 

JiS 
*-° 



Rate per kwh 
for 



o 
3 si 

to*o 



Net monthly bill 
for 



McGarry. . . 
Meaford . . . 

Merlin 

Merrickville . 
Merritton. . 



Midland. . 
Mildmay. 
Millbrook. 
Milton. . . 
Milverton . 



Mimico 

Mitchell 

Moorefield 

Morrisburg. 
Mount Brydges. 



Mount Forest. 

Napanee 

Neustadt 

Newboro 

Newburgh. . . . 



Newbury 

Newcastle 

New Hamburg. 
fNew Liskeard . . 
Newmarket 



New Toronto . 

Niagara 

Niagara Falls . 
Nipigon Twp. 
North Bay. . . 



North York Twp. 

Norwich 

Norwood 

Oakville 

Trafalgar 

Oil Springs 



Omemee. . . 
Orangeville. 

Orillia 

Orono 

Oshawa . . . . 



46 



39 



37 



40 



40 



A 2 



46 



No. 


i 


40 






1.67 


44 


1.67 


38 


1.67 


40 


1.67 


39 


1.67 




1.67 


41 


1.67 


43 


1.67 


45 


1.67 



45 


1.67 


37 


1.67 


40 


1.67 


43 


1.67 


40 


1.67 


41 


1.67 




1.67 


38 


1.67 




1.67 


38 


1.67 


40 


1.67 




1.67 


39 


1.70 


42 


1.67 


37 


1.67 


42 


1.67 




1.67 


30 


1.67 




1.67 


37 


1.67 


42 


1.67 


41 


1.67 


37 


1.67 


45 


1.79 


41 


1.67 




1.67 


36 


1.67 


38 


1.67 


34 


1.67 



No. 
60 
60 
60 
50 
60 

50 
60 
50 
50 
50 

50 
50 
50 
50 
50 

50 
50 
50 
50 
60 

60 
60 
50 
50 
60 

60 
60 
50 
50 
60 

60 
60 
50 
60 
50 
50 

60 
50 
60 
50 
50 



I 

3.5 
2.6 
3.1 
2.8 
3.2 

1.8 
2.5 
3.0 
3.2 
3.4 

2.4 
3.4 
2.6 
2.4 
3.4 

2.6 
2.6 

2.0 
3.2 
4.3 

4.0 
3.0 
3.0 
4.0 
2.5 

2.6 
3.0 
3.0 
2.2 
2.5 

2.7 
3.4 
2.6 
3.0 
3.8 
2.8 

3.3 
3.0 

2.3 
3.0 
2.2 



1.4 



0.9 

1.5 
1.6 
1.7 

1.2 
1.7 
1.3 
1.2 
1.7 

1.3 

1.3 
1.0 
1.6 



1.5 
2.0 



1.4 
1.1 



1.9 

1.4 



1.5 



1.5 
1.1 



0.9 
1.0 

1.0 

0.7 
1.0 
0.7 
0.7 
1.0 

0.8 
0.8 
0.7 
1.0 



0.9 
1.1 



0.7 



1.1 

0.8 



0.8 
0.7 



C 

1.1 
1.0 
1.0 

1.1 

1.3 

1.0 
1.0 
1.2 
1.4 
1.4 

1.0 

1.4 
1.0 
1.0 
1.4 

1.1 
1.1 
1.0 
1.4 
1.2 

1.0 
0.9 
1.2 
1.6 
1.0 

1.2 
1.4 
1.0 
1.0 
1.2 

1.3 
1.2 
1.1 
1.4 
1.5 
1.1 

1.0 

1.2 
0.9 
1.2 
1.0 



$ 
2.29 
1.76 
2.03 
1.89 
2.20 

1.21 
1.71 

2.02 
2.16 
2.29 

1.62 
2.29 
1.75 
1.62 
2.29 

1.75 
1.75 
1.35 
2.16 
2.75 

2.52 
1.94 
2.02 
2.70 
1.71 

1.84 
2.12 
1.98 
1.48 
1.78 

1.93 
2.27 
1.75 
2.12 
2.56 
1.89 

2.14 
2.02 
1.57 
2.02 
1.48 



$ 
4.27 
3.56 
3.83 
4.14 
4.54 

2.74 
3.51 
4.45 
4.77 
5.04 

3.55 
5.04 
3.82 
3.55 
5.04 

3.87 
3.87 
3.01 
4.77 
4.91 

4.32 
3.56 
4.45 
5.89 
3.51 

4.00 
4.64 
4.32 
3.28 
3.94 

4.27 
4.43 
3.87 
4.64 
5.62 
4.14 

3.94 
4.45 
3.19 
4.41 
3.28 



fLocal system 
For explanatory notes and water-heating schedules see pages 240 to 243. 



Statement C 



233 



Utilities and Local Systems 
FOR ELECTRICAL SERVICE 
December 31, 1960 

are subject to 10% prompt payment discount 
monthly charge 



Commercial service 


Industrial power service 


Demand rate 
per 100 watts 






















5.0 cents, 
minimum 50 cents 


Net monthly bill 

for use of 
1 kw of demand 


M 

u 

a 




Energy rate per kwh 

for use of 
each kw of demand 




Net monthly 

for use o 

1 kw of dem 


bill 


Energy rate per 


ind 


kwh for use of 
each kw of demand 








V 

d 

•o 

c 
a 
6 
u 

Q 














0) 

It 
3 
O 

2o 

£2 


en 

3 
O 

z2 


GO 

3 
JL O 

•o- 
33 


03 

3 
O 

JS 

o 

© 


3 
O 
JG 

© 
o 


to 
u 

3 
O 

A 

8 


03 

3 


3 
O 


03 

3 
£° 

c* in 


73 

3 
O 

4-.-G 

k 


M 

3 

.i o 


u 

3 
O 

8 


e/3 

u 

3 
O 

jG 

o 
o 


03 

U 

3 
O 

J3 

O 
O 
I*) 


i 


i 


t 


$ 


$ 


$ 


$ 


J5 


i 


i 


t 


i 


$ 


$ 


$ 


3.0 




1.0 


3.15 


4.05 


4.95 


1.35 


3.1 




2.0 




0.33 


3.51 


3.81 


4.10 


2.2 




0.8 


2.43 


3.15 


3.87 


1.20 


2.1 




1.4 




0.30 


2.65 


2.92 


3.19 


2.6 




0.7 


2.79 


3.42 


4.05 


1.35 


2.8 




1.8 




0.33 


3.28 


3.58 


3.88 


°2.2 


0.8 


0.5 


2.43 


3.15 


3.60 


1.00 




1.1 




0.5 


0.33 


1.89 


2.34 


2.64 


2.7 




1.1 


2.88 


3.87 


4.86 


1.20 


1.9 




1.3 




0.30 


2.52 


2.79 


3.06 


°1.5 


0.8 


0.5 


1.80 


2.52 


2.97 


1.00 




0.8 




0.5 


0.33 


1.62 


2.07 


2.37 


2.0 




0.9 


2.25 


3.06 


3.87 


1.20 


1.9 




1.3 




0.30 


2.52 


2.79 


3.06 


°3.0 


0.8 


0.5 


3.15 


3.87 


4.32 


1.00 




2.2 




0.5 


0.33 


2.88 


3.33 


3.63 


°2.6 


0.8 


0.5 


2.79 


3.51 


3.96 


1.00 




2.1 




0.5 


0.33 


2.79 


3.24 


3.54 


°2.9 


0.8 


0.5 


3.06 


3.78 


4.23 


1.00 




2.1 




0.5 


0.33 


2.79 


3.24 


3.54 


°2.2 


0.8 


0.5 


2.43 


3.15 


3.60 


1.00 




1.5 




0.5 


0.33 


2.25 


2.70 


3.00 


°2.9 


0.8 


0.5 


3.06 


3.78 


4.23 


1.00 




2.1 




0.5 


0.33 


2.79 


3.24 


3.54 


°2.4 


0.8 


0.5 


2.61 


3.33 


3.78 


1.00 




1.9 




0.5 


0.33 


2.61 


3.06 


3.36 


°1.9 


0.8 


0.5 


2.16 


2.88 


3.33 


1.00 




1.4 




0.5 


0.33 


2.16 


2.61 


2.91 


°3.0 


0.8 


0.5 


3.15 


3.87 


4.32 


1.00 




2.3 




0.5 


0.33 


2.97 


3.42 


3.72 


°2.3 


0.8 


0.5 


2.52 


3.24 


3.69 


1.00 




1.8 




0.5 


0.33 


2.52 


2.97 


3.27 


°2.2 


0.8 


0.5 


2.43 


3.15 


3.60 


1.00 




1.3 




0.5 


0.33 


2.07 


2.52 


2.82 


°1.6 


0.8 


0.5 


1.89 


2.61 


3.06 


1.00 




1.0 




0.5 


0.33 


1.80 


2.25 


2.55 


°2.4 


0.8 


0.5 


2.61 


3.33 


3.78 


1.00 




1.6 




0.5 


0.33 


2.34 


2.79 


3.09 


3.8 




1.2 


3.87 


4.95 


6.03 


1.35 


2.5 




1.6 




0.33 


3.06 


3.36 


3.65 


3.5 




0.9 


3.60 


4.41 


5.22 


1.35 


3.5 




2.3 




0.33 


3.82 


4.12 


4.42 


2.5 




0.8 


2.70 


3.42 


4.14 


1.35 


2.0 




1.3 




0.33 


2.70 


3.00 


3.29 


°2.6 


0.8 


0.5 


2.79 


3.51 


3.96 


1.00 




1.9 




0.5 


0.33 


2.61 


3.06 


3.36 


°3.6 


0.8 


0.5 


3.69 


4.41 


4.86 


1.00 




2.4 




0.5 


0.33 


3.06 


3.51 


3.81 


2.2 




1.0 


2.43 


3.33 


4.23 


1.20 


2.1 




1.4 




0.30 


2.65 


2.92 


3.19 


•2.1 


0.8 


0.5 


2.34 


3.06 


3.51 


1.00 




1.4 




0.5 


0.33 


2.16 


2.61 


2.91 


2.5 




1.2 


2.70 


3.78 


4.86 


1.20 


2.1 




1.4 




0.30 


2.65 


2.92 


3.19 


°2.2 


0.8 


0.5 


2.43 


3.15 


3.60 


1.00 




1.5 




0.5 


0.33 


2.25 


2.70 


3.00 


°1.9 


0.8 


0.5 


2.16 


2.88 


3.33 


1.00 




1.2 




0.5 


0.33 


1.98 


2.43 


2.73 


2.0 




0.9 


2.25 


3.06 


3.87 


1.20 


2.1 




1.4 




0.30 


2.65 


2.92 


3.19 


2.2 




1.1 


2.43 


3.42 


4.41 


1.20 


1.7 




1.2 




0.30 


2.38 


2.65 


2.92 


3.0 




1.0 


3.15 


4.05 


4.95 


1.35 


2.5 




1.6 




0.33 


3.06 


3.36 


3.65 


°2.1 


0.8 


0.5 


2.34 


3.06 


3.51 


1.00 




1.6 




0.5 


0.33 


2.34 


2.79 


3.09 


2.5 




1.3 


2.70 


3.87 


5.04 


1.20 


1.7 




1.2 




0.30 


2.38 


2.65 


2.92 


°3.0 


0.8 


0.5 


3.15 


3.87 


4.32 


1.00 




2.4 




0.5 


0.33 


3.06 


3.51 


3.81 


°2.7 


0.8 


0.5 


2.88 


3.60 


4.05 


1.00 




2.2 




0.5 


0.33 


2.88 


3.33 


3.63 


2.8 




0.8 


2.97 


3.69 


4.41 


1.35 


2.8 




1.8 




0.33 


3.28 


3.58 


3.88 


°2.3 


0.8 


0.5 


2.52 


3.24 


3.69 


1.00 




1.4 




0.5 


0.33 


2.16 


2.61 


2.91 


1.8 




0.8 


2.07 


2.79 


3.51 


1.00 


1.4 




0.9 




0.30 


1.93 


2.20 


2.47 


°2.5 


0.8 


0.5 


2.70 


3.42 


3.87 


1.00 




1.7 




0.5 


0.33 


2.43 


2.88 


3.18 


°1.8 


0.8 


0.5 


2.07 


2.79 


3.24 


1.00 




1.2 




0.5 


0.33 


1.98 


2.43 


2.73 



234 



Municipal Electrical Service 

Municipal Electrical 
RATES AND TYPICAL BILLS 

in effect 

Rates are quoted on a monthly basis and 
and a minimum 



Municipality 



M 

C 

IS 

$2 


■ 

E 

3 

C 

3 






M 

i 

60 

C 


T3 

"a 
a 




St 

In 






rt 


go 


fc.s 


s 




O 


E 






X 


3 






■ 


z 



Residential service 



Rate per kwh 
for 



o 

£"0 















«N 


tr, 






XJ5 


X-fi 




2 * 



Net monthly bill 
for 



Ottawa (including East- 
view and Rockcliffe 
Park) 

Otterville 

Owen Sound 

Paisley 

Palmerston 



Paris 

Parkhill 

Parry Sound 

Penetanguishene . 
Perth 



Peterborough 

Petrolia 

Pickering 

t Pickle Lake Landing 

Townsite 

Picton 



Plattsville. 
Point Edward. 
Port Arthur... 
Port Burwell.. 
fPort Carling. . 



Port Colborne. 

Port Credit 

Port Dalhousie. 
Port Dover. .. . 
Port Elgin 



Port Hope. . . . 
Port MeNicoll 
Port Perry. . . 
Port Rowan. . 
Port Stanley. . 



fPowassan 
Prescott. . 
Preston. . 
PriceviJJe. 
Princeton . 



Queenston 

Rainy River. . . 
fRed Lake Twp. 

Red Rock 

Renfrew 



i No. 



37 



42 



5 7 



43 



i 


No. 
a/60 


i 

*/2.0 


i 


i 


i 


$ 




\60 


\1.0 






*0.5 


1.74 


1.67 


60 


3.0 






1.0 


1.98 


1.67 


60 


2.4 






1.1 


1.69 


1.67 


60 


3.5 






1.0 


2.25 




60 


2.6 






1.0 


1.76 


1.67 


60 


2.8 






1.3 


1.98 


1.78 


50 


3.2 


1.6 


0.9 


1.3 


2.16 


1.67 


50 


3.4 


1.7 


1.0 


1.4 


2.29 


1.67 


50 


2.2 


1.1 


0.7 


1.0 


1.48 


1.67 


50 


2.4 


1.2 


0.7 


1.0 


1.62 


1.67 


60 


2.6 






1.3 


1.87 


1.67 


50 


3.2 


1.6 


1.0 


1.4 


2.16 


1.67 


50 


4.0 


2.0 


1.1 


1.6 


2.70 


1.67 


50 


4.4 


2.2 


1.2 


1.6 


2.97 


1.67 


50 


2.6 


1.3 


0.8 


1.1 


1.75 




50 


2.8 


1.4 


0.8 


1.1 


1.89 


1.67 


50 


2.2 


1.1 


0.7 


1.0 


1.48 


1.67 


60 


2.0 






0.8 


1.37 




50 


4.4 


2.2 


1.3 


1.6 


2.97 


1.67 


50 


4.4 


2.2 


1.2 


1.6 


2.97 


1.67 


60 


2.8 






1.2 


1.94 


1.67 


50 


2.8 


1.4 


0.8 


1.1 


1.89 


1.78 


50 


3.8 


1.9 


1.1 


1.5 


2.56 


1.67 


60 


2.4 






1.2 


1.73 


1.80 


60 


3.5 






1.3 


2.36 


1.67 


50 


3.0 


1.5 


0.9 


1.2 


2.02 


1.67 


50 


2.6 


1.3 


0.8 


1.1 


1.75 


1.67 


50 


2.6 


1.3 


0.7 


1.0 


1.75 


1.78 


50 


2.8 


1.4 


0.8 


1.1 


1.89 


1.67 


50 


3.2 


1.6 


1.0 


1.4 


2.16 


1.67 


50 


3.6 


1.8 


1.0 


1.4 


2.43 


1.67 


50 


2.2 


1.1 


0.7 


1.0 


1.48 


1.67 


50 


3.0 


1.5 


0.9 


1.2 


2.02 


1.67 


50 


4.0 


2.0 


1.2 


1.6 


2.70 


1.67 


60 


3.0 






1.0 


1.98 


1.67 


50 


2.6 


1.3 


0.8 


1.1 


1.75 




50 


6.8 


3.4 




1.6 


4.59 


1.67 


50 


4.4 


2.2 


1.2 


1.6 


2.97 


1.67 


50 


2.4 


1.2 


0.7 


1.0 


1.62 


1.67 


50 


2.6 


1.3 


0.7 


1.0 


1.75 



3.02 
3.78 
3.67 
4.05 
3.56 

4.32 
4.72 
5.04 
3.28 
3.55 

4.21 
4.77 
5.89 

6.48 
3.87 

4.14 
3.28 
2.81 
6.52 
6.48 

4.10 
4.14 
5.62 
3.89 
4.70 

4.45 
3.87 
3.82 
4.14 
4.77 

5.31 
3.28 
4.45 
5.94 
3.78 

3.87 
9.90 
6.48 
3.55 
3.82 



tLocal system 
For explanatory notes and water-heating schedules see pages 240 to 243. 



Statement C 



235 



Utilities and Local Systems 
FOR ELECTRICAL SERVICE 
December 31, 1960 

are subject to 10% prompt payment discount 
monthly charge 



Commercial service 


Industrial power service 


Demand rate 
per 100 watts 




















5.0 cents, 
minimum 50 cents 


Net monthly bill 

for use of 
1 kw of demand 


hi 

o. 


Energy rate per kwh 

for use of 
each kw of demand 




Net monthly 

for use of 

1 kw of dema 


bill 


Energy rate per 

kwh for use of 

each kw of demand 


nd 








eg 

T3 
G 
ca 

a 

Q 












u 

1 


e 

3 
O 

11 


a 

3 

■S-c 
3* 


TO 

U 

3 
O 

JS 
O 

o 


u 

3 
O 

•C 
o 
o 


TO 

3 
O 

8 


TO 

3 
toJC 


TO 

3 
O 

Co 

£2 


2 

3 
£° 


TO 

a 

3 
O 

II 


3 
.J. o 

3-2 


TO 

3 
O 

J5 

s 


TO 

3 
O 

A 

8 


TO 

3 
O 

A 

8 


t 


i 


i 


$ 


$ 


$ 


$ 


i 


i 


t 


t 


i 


$ 


$ 


$ 


2.0 


0.8 


0.5 


2.25 


2.97 


3.42 


1.00 




1.4 




0.5 


0.33 


2.16 


2.61 


2.91 


2.5 




0.8 


2.70 


3.42 


4.14 


1.35 


2.0 




1.3 




0.33 


2.70 


3.00 


3.29 


°2.0 


0.8 


0.5 


2.25 


2.97 


3.42 


1.00 


1.5 




1.1 




0.30 


2.07 


2.34 


2.61 


3.0 




1.0 


3.15 


4.05 


4.95 


1.35 


2.6 




1.7 




0.33 


3.15 


3.45 


3.74 


2.2 




0.8 


2.43 


3.15 


3.87 


1.20 


1.6 




1.0 




0.30 


2.25 


2.52 


2.79 


2.3 




0.8 


2.52 


3.24 


3.96 


1.00 


1.5 




1.1 




0.30 


2.07 


2.34 


2.61 


°2.9 


0.8 


0.5 


3.06 


3.78 


4.23 


1.00 




2.2 




0.5 


0.33 


2.88 


3.33 


3.63 


°2.8 


0.8 


0.5 


2.97 


3.69 


4.14 


1.00 




2.1 




0.5 


0.33 


2.79 


3.24 


3.54 


°1.6 


0.8 


0.5 


1.89 


2.61 


3.06 


1.00 




1.0 




0.5 


0.33 


1.80 


2.25 


2.55 


°1.7 


0.8 


0.5 


1.98 


2.70 


3.15 


1.00 




0.9 




0.5 


0.33 


1.71 


2.16 


2.46 


2.1 




1.2 


2.34 


3.42 


4.50 


1.20 


1.4 




0.9 




0.30 


2.11 


2.38 


2.65 


3.2 


0.8 


0.5 


3.33 


4.05 


4.50 


1.00 




2.7 




0.5 


0.33 


3.33 


3.78 


4.08 


°2.2 


0.8 


0.5 


2.43 


3.15 


3.60 


1.00 




1.6 




0.5 


0.33 


2.34 


2.79 


3.09 


°3.9 


0.8 


0.5 


3.96 


4.68 


5.13 


1.00 




3.4 




0.5 


0.33 


3.96 


4.41 


4.71 


2.1 


0.8 


0.5 


2.34 


3.06 


3.51 


1.00 




1.6 




0.5 


0.33 


2.34 


2.79 


3.09 


°2.6 


0.8 


0.5 


2.79 


3.51 


3.96 


1.00 




2.0 




0.5 


0.33 


2.70 


3.15 


3.45 


°1.9 


0.8 


0.5 


2.16 


2.88 


3.33 


1.00 




1.4 




0.5 


0.33 


2.16 


2.61 


2.91 


1.9 




0.4 


2.16 


2.52 


2.88 


1.00 


1.4 




0.9 




0.25 


1.93 


2.16 


2.38 


°3.4 


0.8 


0.5 


3.51 


4.23 


4.68 


1.00 




2.5 




0.5 


0.33 


3.15 


3.60 


3.90 


°4.2 


0.8 


0.5 


4.23 


4.95 


5.40 


1.00 




2.7 




0.5 


0.33 


3.33 


3.78 


4.08 


2.5 




1.1 


2.70 


3.69 


4.68 


1.20 


1.9 




1.3 




0.30 


2.52 


2.79 


3.06 


°2.2 


0.8 


0.5 


2.43 


3.15 


3.60 


1.00 




1.7 




0.5 


0.33 


2.43 


2.88 


3.18 


°2.8 


0.8 


0.5 


2.97 


3.69 


4.14 


1.00 




2.3 




0.5 


0.33 


2.97 


3.42 


3.72 


2.0 




1.0 


2.25 


3.15 


4.05 


1.20 


1.7 




1.2 




0.30 


2.38 


2.65 


2.92 


2.8 




1.0 


2.97 


3.87 


4.77 


1.35 


2.5 




1.6 




0.33 


3.06 


3.36 


3.65 


°2.3 


0.8 


0.5 


2.52 


3.24 


3.69 


1.00 




1.6 




0.5 


0.33 


2.34 


2.79 


3.09 


°2.4 


0.8 


0.5 


2.61 


3.33 


3.78 


1.00 




1.9 




0.5 


0.33 


2.61 


3.06 


3.36 


°1.9 


0.8 


0.5 


2.16 


2.88 


3.33 


1.00 




1.4 




0.5 


0.33 


2.16 


2.61 


2.91 


°2.5 


0.8 


0.5 


2.70 


3.42 


3.87 


1.00 




2.0 




0.5 


0.33 


2.70 


3.15 


3.45 


°2.9 


0.8 


0.5 


3.06 


3.78 


4.23 


1.00 




2.4 




0.5 


0.33 


3.06 


3.51 


3.81 


3.4 


0.8 


0.5 


3.51 


4.23 


4.68 


1.00 




2.7 




0.5 


0.33 


3.33 


3.78 


4.08 


°2.1 


0.8 


0.5 


2.34 


3.06 


3.51 


1.00 




1.3 




0.5 


0.33 


2.07 


2.52 


2.82 


°2.5 


0.8 


0.5 


2.70 


3.42 


3.87 


1.00 




1.5 




0.5 


0.33 


2.25 


2.70 


3.00 


3.8 


0.8 


0.5 


3.87 


4.59 


5.04 


1.00 




2.9 




0.5 


0.33 


3.51 


3.96 


4.26 


2.7 




0.8 


2.88 


3.60 


4.32 


1.20 


2.1 




1.4 




0.30 


2.65 


2.92 


3.19 


°2.4 


0.8 


0.5 


2.61 


3.33 


3.78 


1.00 




1.8 




0.5 


0.33 


2.52 


2.97 


3.27 


°6.0 


0.8 


0.5 


5.85 


6.57 


7.02 


1.00 




5.0 




0.8 


0.50 


5.40 


6.12 


6.57 


°3.9 


0.8 


0.5 


3.96 


4.68 


5.13 


1.00 




3.4 




0.5 


0.33 


3.96 


4.41 


4.71 


•1.7 


0.8 


0.5 


1.98 


2.70 


3.15 


1.00 




0.9 




0.5 


0.33 


1.71 


2.16 


2.46 


°1.8 


0.8 


0.5 


2.07 


2.79 


3.24 


1.00 




1.2 




0.5 


0.33 


1.98 


2.43 


2.73 



236 



Municipal Electrical Service 



Municipal Electrical 
RATES AND TYPICAL BILLS 

in effect 

Rates are quoted on a monthly basis and 
and a minimum 



Municipality 



to 












Hi CO 


E 

3 




•a 
.S 

"a 


OS* 


C 


a 


3 .id 

CO CJ 


rt O 




c 


JS.2 


>o 


3 


^•° 


<u u 


"3 


a) 
a; 


** 


h& 


£ 


o<c 


rt 


r 


CO 

3 


M 


s 




O 


H 

3 






£ 






■ 


z 



Residential service 



Rate per kwh 
for 



CJ 

O 

3.C 

CO j^ 

2*0 



o 


o 


o 


© 


CN 


ID 






XJS 


XJ3 


cy > 


7^M 



Net monthly bill 
for 



Richmond 

Richmond Hill. 
Ridgetown. . . . 

Ripley 

Riverside 



Rockland. 
Rockwood . 
Rodney. . . 
Rosseau . . . 
Russell. . . . 



Catharines . 
Clair Beach 

George 

Jacobs 

Mary's 



St. Thomas 

Sandwich East Twp. . 
Sandwich West Twp. . 

Sarnia 

Scarborough Twp.. . . 



Schreiber Twp. 

Seaforth 

Shelburne. 

Simcoe 

Sioux Lookout. 



Smith's Falls. . . 

Smithville 

Southampton. . . 
fSouth Porcupine 

Townsite 

Springfield 



Stamford Twp. 

Stayner 

Stirling 

Stoney Creek. 
Stouffville. . . . 



Stratford 

Strathroy . . . . 
Streetsville. . . 
Sturgeon Falls. 
Sudbury 



i No. 


i 


No. 


t 


i 


i 


35 


1.67 


50 


3.0 


1.5 


0.8 


43 


1.67 


50 


3.4 


1.7 


1.0 


45 


1.67 


60 


2.9 






43 


1.67 


50 


2.8 


1.4 


0.8 


36 


1.67 


50 


3.2 


1.6 


0.9 


36 


1.67 


50 


2.6 


1.3 


0.8 


45 


1.67 


50 


3.0 


1.5 


0.9 


45 


1.67 


60 


2.5 






43 


1.67 


50 


3.4 


1.7 


1.0 


36 


1.67 


50 


2.2 


1.1 


0.7 


42 


1.67 


60 


2.7 






42 


1.67 


50 


3.6 


1.8 


1.1 


44 


1.67 


50 


2.0 


1.0 


0.7 


42 


1.67 


60 


3.0 






43 


1.67 


50 


3.0 


1.5 


0.9 


43 


1.67 


60 


3.2 






41 


1.67 


50 


4.4 


2.2 


1.2 


41 


1.67 


50 


4.0 


2.0 


1.1 


40 


1.67 


50 


3.0 


1.5 


0.9 


37 


1.67 


50 


3.0 


1.5 


0.9 


31 


1.67 


50 


2.0 


1.0 


0.7 


36 


1.67 


50 


3.0 


1.5 


0.8 


43 


1.67 


50 


2.8 


1.4 


0.8 


41 


1.67 


50 


2.2 


1.1 


0.7 


53 


1.67 


60 


4.0 






38 




60 


2.6 






44 


1.78 


60 


3.2 






45 


1.67 


50 


3.2 






42 


1.67 


50 


3.4 


1.7 


1.0 


41 


1.67 


50 


2.6 


1.3 


0.7 


40 


1.67 


60 


3.2 






41 


1.67 


60 


3.0 






38 


1.67 


50 


2.8 


1.4 


0.8 


41 


1.67 


50 


3.0 


1.5 


0.8 


44 


1.67 


50 


3.4 


1.7 


1.0 


40 


1.67 


60 


2.9 






37 


1.67 


50 


2.8 


1.4 


0.8 


43 


1.67 


60 


2.9 






40 


1.67 


50 


3.2 


1.6 


1.0 


37 


1.67 


60 


2.6 







i 

1.2 
1.4 
1.1 
1.1 
1.3 

1.1 
1.2 
1.0 
1.4 
1.0 

1.5 
1.5 
1.0 
1.1 
1.2 

1.2 
1.6 
1.6 
1.2 
1.2 

1.0 
1.2 
1.1 
1.0 
1.5 

1.0 
1.2 
1.1 

1.4 
1.0 

1.4 
1.2 
1.1 
1.2 
1.4 

1.2 
1.1 
1.3 
1.4 
1.2 



% 
2.02 
2.29 
1.96 
1.89 
2.16 

1.75 
2.02 
1.71 
2.29 
1.48 

2.00 
2.43 
1.35 
2.02 
2.02 

2.16 
2.97 
2.70 
2.02 
2.02 

1.35 
2.02 
1.89 
1.48 
2.70 

1.76 
2.16 
1.93 

2.29 
1.75 

2.23 
2.05 
1.89 
2.02 
2.29 

2.00 
1.89 
2.03 
2.16 
1.84 



$ 
4.41 
5.04 
3.94 
4.14 
4.72 

3.87 
4.45 
3.51 
5.04 
3.28 

4.70 
5.35 
3.01 
4.00 
4.45 

4.32 
6.48 
5.89 
4.45 
4.45 

3.01 
4.41 
4.14 
3.28 
5.40 

3.56 
4.32 
3.91 

5.04 
3.82 

4.75 
4.21 
4.14 
4.41 
5.04 

4.16 
4.14 
4.37 

4.77 
4.00 



tLocal system 
For explanatory notes and water-heating schedules see pages 240 to 243. 



Statement C 



237 



Utilities and Local Systems 
FOR ELECTRICAL SERVICE 
December 31, 1960 

are subject to 10% prompt payment discount 
monthly charge 



Commercial service 


Industrial power service 


Demand rate 
per 100 watts 






















5.0 cents, 
minimum 50 cents 


Net monthly bill 

for use of 
1 kw of demand 


M 

<v 

a 




Energy rate per kwh 

for use of 
each kw of demand 




Net monthly 

for use o 

1 kw of dem 


bill 
f 


Energy rate per 


and 


kwh for use of 
each kw of demand 








a 
X) 

a 
cd 

E 

0) 

Q 














eo 
k< 

3 
O 


DO 

3 
O 

II 


e 

■3 .a 

33 


CO 

c 

3 
O 
J3 
O 
O 


CO 

a 

3 
O 

Si 

o 

o 


3 
O 

s 

to 


3 
;-© 


u 

3 
O 

S2 


CO 

3 

£° 


CO 

u 
3 
O 

z2 


CO 

3 

3-B 


3 
O 

o 
o 


co 
hi 

3 
O 

J3 

O 
O 


3 
O 

§ 


i 


* 


* 


$ 


$ 


$ 


$ 


i 


^ 


t 


i 


i 


$ 


$ 


$ 


°2.6 


0.8 


0.5 


2.79 


3.51 


3.96 


1.00 




2.1 




0.5 


0.33 


2.79 


3.24 


3.54 


°2.7 


0.8 


0.5 


2.88 


3.60 


4.05 


1.00 




2.1 




0.5 


0.33 


2.79 


3.24 


3.54 


2.4 




0.9 


2.61 


3.42 


4.23 


1.35 


2.2 




1.4 




0.33 


2.83 


3.13 


3.43 


°2.5 


0.8 


0.5 


2.70 


3.42 


3.87 


1.00 




1.8 




0.5 


0.33 


2.52 


2.97 


3.27 


°2.4 


0.8 


0.5 


2.61 


3.33 


3.78 


1.00 




1.7 




0.5 


0.33 


2.43 


2.88 


3.18 


°2.1 


0.8 


0.5 


2.34 


3.06 


3.51 


1.00 




1.3 




0.5 


0.33 


2.07 


2.52 


2.82 


°2.6 


0.8 


0.5 


2.79 


3.51 


3.96 


1.00 




2.1 




0.5 


0.33 


2.79 


3.24 


3.54 


2.2 




0.8 


2.43 


3.15 


3.87 


1.35 


2.2 




1.4 




0.33 


2.83 


3.13 


3.43 


°2.9 


0.8 


0.5 


3.06 


3.78 


4.23 


1.00 




2.1 




0.5 


0.33 


2.79 


3.24 


3.54 


°1.6 


0.8 


0.5 


1.89 


2.61 


3.06 


1.00 




1.1 




0.5 


0.33 


1.89 


2.34 


2.64 


c2.3 




1.1 


2.52 


3.51 


4.50 


1.20 


1.9 




1.3 




0.30 


2.52 


2.79 


3.06 


°3.0 


0.8 


0.5 


3.15 


3.87 


4.32 


1.00 




2.3 




0.5 


0.33 


2.97 


3.42 


3.72 


°1.8 


0.8 


0.5 


2.07 


2.79 


3.24 


1.00 




1.5 




0.5 


0.33 


2.25 


2.70 


3.00 


2.5 




1.0 


2.70 


3.60 


4.50 


1.20 


1.7 




1.2 




0.30 


2.38 


2.65 


2.92 


°2.5 


0.8 


0.5 


2.70 


3.42 


3.87 


1.00 




1.5 




0.5 


0.33 


2.25 


2.70 


3.00 


2.3 




0.6 


2.52 


3.06 


3.60 


1.20 


1.6 




1.0 




0.30 


2.25 


2.52 


2.79 


°3.9 


0.8 


0.5 


3.96 


4.68 


5.13 


1.00 




3.4 




0.5 


0.33 


3.96 


4.41 


4.71 


°3.3 


0*8 


0.5 


3.42 


4.14 


4.59 


1.00 




2.8 




0.5 


0.33 


3.42 


3.87 


4.17 


°2.7 


0.8 


0.5 


2.88 


3.60 


4.05 


1.00 




1.6 




0.5 


0.33 


2.34 


2.79 


3.09 


°2.2 


0.8 


0.5 


2.43 


3.15 


3.60 


1.00 




1.7 




0.5 


0.33 


2.43 


2.88 


3.18 


°1.7 


0.8 


0.5 


1.98 


2.70 


3.15 


1.00 




1.2 




0.5 


0.33 


1.98 


2.43 


2.73 


°2.3 


0.8 


0.5 


2.52 


3.24 


3.69 


1.00 




1.6 




0.5 


0.33 


2.34 


2.79 


3.09 


°2.2 


0.8 


0.5 


2.43 


3.15 


3.60 


1.00 




1.5 




0.5 


0.33 


2.25 


2.70 


3.00 


°1.9 


0.8 


0.5 


2.16 


2.88 


3.33 


1.00 




1.4 




0.5 


0.33 


2.16 


2.61 


2.91 


3.5 




2.0 


3.60 


5.40 


7.20 


1.35 


2.8 




1.8 




0.33 


3.28 


3.58 


3.88 


2.0 




0.7 


2.25 


2.88 


3.51 


1.00 


1.5 




1.1 




0.25 


2.07 


2.29 


2.52 


2.8 




1.1 


2.97 


3.96 


4.95 


1.35 


2.5 




1.6 




0.33 


3.06 


3.36 


3.65 


2.9 




1.1 


3.06 


4.05 


5.04 


1.35 


2.2 




1.4 




0.33 


2.83 


3.13 


3.43 


•3.3 


0.8 


0.5 


3.42 


4.14 


4.59 


1.00 




2.4 




0.5 


0.33 


3.06 


3.51 


3.81 


■1.9 


0.8 


0.5 


2.16 


2.88 


3.33 


1.00 




1.4 




0.5 


0.33 


2.16 


2.61 


2.91 


2.9 




1.3 


3.06 


4.23 


5.40 


1.20 


1.9 




1.3 




0.30 


2.52 


2.79 


3.06 


2.5 




1.2 


2.70 


3.78 


4.86 


1.20 


1.9 




1.3 




0.30 


2.52 


2.79 


3.06 


°2.2 


0.8 


0.5 


2.43 


3.15 


3.60 


1.00 




1.3 




0.5 


0.33 


2.07 


2.52 


2.82 


°2.4 


0.8 


0.5 


2.61 


3.33 


3.78 


1.00 




1.7 




0.5 


0.33 


2.43 


2.88 


3.18 


°3.1 


0.8 


0.5 


3.24 


3.96 


4.41 


1.00 




2.5 




0.5 


0.33 


3.15 


3.60 


3.90 


2.4 




0.7 


2.61 


3.24 


3.87 


1.20 


1.7 




1.2 




0.30 


2.38 


2.65 


2.92 


°2.4 


0.8 


0.5 


2.61 


3.33 


3.78 


1.00 




1.7 




0.5 


0.33 


2.43 


2.88 


3.18 


2.4 




1.3 


2.61 


3.78 


4.95 


1.20 


2.1 




1.4 




0.30 


2.65 


2.92 


3.19 


°2.6 


0.8 0.5 


2.79 


3.51 


3.96 


1.00 




2.0 




0.5 


0.33 


2.70 


3.15 


3.45 


2.4 


... 


1.2 1 


2.61 


3.69 


4.77 


1.35 


2.0 




1.3 




0.33 


2.70 


3.00 


3.29 



238 



Municipal Electrical Service 



Municipal Electrical 
RATES AND TYPICAL BILLS 

in effect 

Rates are quoted on a monthly basis and 
and a minimum 









Residential service 


Municipality 


be 
c 

St, 


X) 

E 

3 

e 

cv 

3 
"0 

V 


M 

u 

a 
bo 
c 

I 

J3 
U 

3 
O 

X 

m 


"E. 
a 

03 (J 

*i 

"Big 

«.s 

E 
s 
Z 


Rate per kwh 
for 


Net monthly bill 
for 






M 

o 
o 

to"S 




§ 


3-2 


o 

o 


M 

8 


JZ 

§ 

1/5 




i No. 
40 

45 
45 
37 

44 

39 
41 

42 

32 
45 

45 
45 
48 
42 
42 

42 
39 
40 
45 
40 

42 

** 

37 
43 

34 

37 
39 
40 
43 

38 

41 

52 

38 
42 
42 

42 
35 
45 
42 
43 


i 

1.67 
1.67 
1.78 

1.67 

1.67 
1.67 
1.67 
1.67 
1.67 

1.67 
1.67 
1.67 
1.67 
1.67 

1.67 
1.67 
1.67 
1.67 
1.67 

1.67 

2.10 
1.67 
1.67 

1.67 

1.67 
1.67 
1.67 
1.67 
1.67 

1.67 

1.67 

1.67 
1.67 
1.67 
1.67 


No. 
50 
50 
60 
50 
50 

60 
50 
50 
50 
50 

50 
50 
50 
60 
50 

50 
60 
50 
50 
50 

50 

60 
50 
50 

50 

50 
50 
50 
60 
50 

50 
60 
50 
50 
60 

50 
60 
50 
60 
60 


2.6 
3.4 
2.7 
2.4 
2.6 

2.7 
3.6 
2.6 
1.8 
3.4 

2.8 
2.6 
4.0 
3.5 
3.2 

4.0 
3.8 
3.2 
3.0 
2.8 

3.4 

2.0 
3.2 
2.6 

2.4 

1.8 
2.6 
3.4 
3.2 
2.6 

2.4 
3.6 
2.6 
3.6 
2.6 

3.2 
2.6 
2.8 
3.2 
6.0 


i 

1.3 
1.7 

1.2 
1.3 

1.8 
1.3 
0.9 
1.7 

1.4 
1.3 
2.0 

1.6 

2.0 

1.6 
1.5 
1.4 

1.7 

1.6 
1.3 

1.2 

0.9 
1.3 

1.7 

1.3 

1.2 

1.3 
1.8 

1.6 
1.4 


i 

0.7 
1.0 

0.7 
0.8 

1.0 
0.8 
0.7 
1.0 

0.8 
0.7 
1.2 

1.0 

1.1 

0.9 
0.8 

1.0 

1.0 
0.8 

0.7 

0.7 
0.7 
1.0 

0.8 

0.7 

0.8 
1.1 

0.9 
0.8 


i 

1.0 
1.4 
1.0 
1.0 
1.1 

1.4 
1.4 
1.1 
1.0 
1.4 

1.1 
1.0 
1.6 
1.3 
1.4 

1.6 
1.0 
1.3 
1.2 
1.1 

1.4 

1.4 
1.4 
1.1 

1.0 

1.0 
1.0 
1.4 
1.3 
1.1 

1.0 
0.9 
1.1 
1.5 
1.2 

1.3 

1.1 
1.2 
2.5 


$ 

1.75 
2.29 
1.82 
1.62 
1.75 

1.96 
2.43 
1.75 
1.21 
2.29 

1.89 
1.75 
2.70 
2.36 
2.16 

2.70 
2.41 
2.16 
2.02 
1.89 

2.29 

1.58 
2.16 
1.75 

1.62 

1.21 
1.75 
2.29 
2.20 
1.75 

1.62 

2.27 
1.75 
2.43 
1.84 

2.16 
1.80 
1.89 
2.16 

4.14 


$ 

3.82 
5.04 
3.62 
3.55 
3.87 

4.48 
5.31 
3.87 
2.74 
5.04 

4.14 
3.82 
5.94 
4.70 
4.77 

5.89 
4.21 
4.90 
4.45 
4.14 

5.04 

4.10 
4.77 
3.87 

3.55 

2.74 
3.82 
5.04 
4.54 
3.87 

3.55 
3.89 
3.87 
5.35 
4.00 

4.72 
3.78 
4.14 
4.32 
8.64 


$ 

5.08 




6.84 




5.42 




4.81 


Tara 


5.31 


Tavistock 


7.00 




7.11 




5.31 


Terrace Bay Twp 

Thamesford 


4.00 
6.84 


Thamesville 


5.58 


Thedford 


5.08 


Thessalon 


8.10 


Thornbury 


7.04 


Thorndale. ... .... 


6.57 

7.87 
6.01 
7.24 
6.07 
5.58 

6.84 

6.62 
6.57 
5.31 

4.81 

4.00 
5.08 
6.84 
6.88 
5.31 

4.81 
5.51 
5.31 


fThornloe 


Thornton 


Thorold . 


Tilbury 


Tillsonburg. . 


fTimmins (including 

Schumacher) 


Toronto (including 
Leaside) 


Toronto Twp 


Tottenham 


JTrafalgar Twp. . . 


Trenton 


Tweed 


Uxbridge 


Vankleek Hill 


Victoria Harbour 

VValkerton 


Wallaceburg. . . . 


Wardsville 


Warkworth 


Wasaga Beach 


7.33 


Waterdown 


6.16 


VVaterford 


6.34 


Waterloo 


5.76 


Watford 


5.58 




6.48 


Webbwood 


13.14 



tLocal system JSee Oakville-Trafalgar 

For explanatory notes and water-heating schedules see pages 240 to 243. 



Statement C 



239 



Utilities and Local Systems 
FOR ELECTRICAL SERVICE 
December 31, 1960 

are subject to 10% prompt payment discount 
monthly charge 



Commercial service 


Industrial power service 


Demand rate 




















per 100 watts 




















5.0 cents, 
minimum 50 cents 


Net 


monthly bill 


£ 

.* 


Energy rate per kwh 




Net 


monthly bill 




tor use of 
1 kw of demand 


V 

a 


for use of 
each kw of demand 




for use o 
1 kw of dem 




Energy rate per 


unl 


kwh for use of 








u 












each kw of demand 








« 

-a 
c 
«i 
6 

eu 

Q 












CO 

3 

o 

J 8 

u«2 


CO 

3 
O 


CO 

C 

5-9 


CO 

3 
O 

8 


CO 

3 
O 

J3 

O 
O 
CN 


CO 

H 

3 
O 

X! 

© 
o 


3 
mJS 


CO 

1 

£2 


co 

Ih 

3 

-*• 2 

£° 


3 
O 

II 


to 

3 

•J. o 
•o-c 


i2 

3 
O 

.c 

§ 


CO 

3 
O 

.a 

8 

CN 


h 

3 
O 

A 

8 

en 


i 


* 


* 


$ 


$ 


$ 


$ 


t 


i 


i 


i 


i 


$ 


$ 


$ 


°2.3 


0.8 


0.5 


2.52 


3.24 


3.69 


1.00 




1.8 




0.5 


0.33 


2.52 


2.97 


3.27 


°3.0 


0.8 


0.5 


3.15 


3.87 


4.32 


1.00 




2.5 




0.5 


0.33 


3.15 


3.60 


3.90 


2.4 




0.7 


2.61 


3.24 


3.87 


1.35 


2.0 




1.3 




0.33 


2.70 


3.00 


3.29 


•1.9 


0.8 


0.5 


2.16 


2.88 


3.33 


1.00 




1.3 




0.5 


0.33 


2.07 


2.52 


2.82 


°2.4 


0.8 


0.5 


2.61 


3.33 


3.78 


1.00 




1.9 




0.5 


0.33 


2.61 


3.06 


3.36 


2.3 




1.4 


2.52 


3.78 


5.04 


1.35 


2.2 




1.4 




0.33 


2.83 


3.13 


3.43 


°2.9 


0.8 


0.5 


3.06 


3.78 


4.23 


1.00 




2.1 




0.5 


0.33 


2.79 


3.24 


3.54 


°2.3 


0.8 


0.5 


2.52 


3.24 


3.69 


1.00 




1.8 




0.5 


0.33 


2.52 


2.97 


3.27 


°1.4 


0.8 


0.5 


1.71 


2.43 


2.88 


1.00 




0.9 




0.5 


0.33 


1.71 


2.16 


2.46 


°2.9 


0.8 


0.5 


3.06 


3.78 


4.23 


1.00 




2.4 




0.5 


0.33 


3.06 


3.51 


3.81 


"2.3 


0.8 


0.5 


2.52 


3.24 


3.69 


1.00 




1.7 




0.5 


0.33 


2.43 


2.88 


3.18 


°2.4 


0.8 


0.5 


2.61 


3.33 


3.78 


1.00 




1.8 




0.5 


0.33 


2.52 


2.97 


3.27 


4.0 


0.8 


0.5 


4.05 


4.77 


5.22 


1.00 




3.2 




0.5 


0.33 


3.78 


4.23 


4.53 


3.1 




1.3 


3.24 


4.41 


5.58 


1.20 


1.9 




1.3 




0.30 


2.52 


2.79 


3.06 


°2.7 


0.8 


0.5 


2.88 


3.60 


4.05 


1.00 




1.9 




0.5 


0.33 


2.61 


3.06 


3.36 


°3.6 


0.8 


0.5 


3.69 


4.41 


4.86 


1.00 




2.4 




0.5 


0.33 


3.06 


3.51 


3.81 


3.3 




1.0 


3.42 


4.32 


5.22 


1.35 


2.8 




1.8 




0.33 


3.28 


3.58 


3.88 


2.5 


0.8 


0.5 


2.70 


3.42 


3.87 


1.00 




1.5 




0.5 


0.33 


2.25 


2.70 


3.00 


°2.6 


0.8 


0.5 


2.79 


3.51 


3.96 


1.00 




1.9 




0.5 


0.33 


2.61 


3.06 


3.36 


°2.3 


0.8 


0.5 


2.52 


3.24 


3.69 


1.00 




1.6 




0.5 


0.33 


2.34 


2.79 


3.09 


°3.3 


0.8 


0.5 


3.42 


4.14 


4.59 


1.00 




2.4 




0.5 


0.33 


3.06 


3.51 


3.81 


b2.1 




0.7 


2.65 


3.28 


3.91 


1.10 


2.1 




1.4 




0.38 


2.56 


2.91 


3.25 


°2.6 


0.8 


0.5 


2.79 


3.51 


3.96 


1.00 




2.0 




0.5 


0.33 


2.70 


3.15 


3.45 


°2.6 


0.8 


0.5 


2.79 


3.51 


3.96 


1.00 




2.1 




0.5 


0.33 


2.79 


3.24 


3.54 


°1.9 


0.8 


0.5 


2.16 


2.88 


3.33 


1.00 




1.3 




0.5 


0.33 


2.07 


2.52 


2.82 


°1.6 


0.8 


0.5 


1.89 


2.61 


3.06 


1.00 




0.8 




0.5 


0.33 


1.62 


2.07 


2.37 


°2.4 


0.8 


0.5 


2.61 


3.33 


3.78 


1.00 




1.9 




0.5 


0.33 


2.61 


3.06 


3.36 


•2.7 


0.8 


0.5 


2.88 


3.60 


4.05 


1.00 




2.0 




0.5 


0.33 


2.70 


3.15 


3.45 


2.7 




1.3 


2.88 


4.05 


5.22 


1.35 


2.8 




1.8 




0.33 


3.28 


3.58 


3.88 


°2.3 


0.8 


0.5 


2.52 


3.24 


3.69 


1.00 




1.4 




0.5 


0.33 


2.16 


2.61 


2.91 


°1.9 


0.8 


0.5 


2.16 


2.88 


3.33 


1.00 




1.3 




0.5 


0.33 


2.07 


2.52 


2.82 


3.2 




0.8 


3.33 


4.05 


4.77 


1.35 


2.8 




1.8 




0.33 


3.28 


3.58 


3.88 


°2.2 


0.8 


0.5 


2.43 


3.15 


3.60 


1.00 




1.5 




0.5 


0.33 


2.25 


2.70 


3.00 


°3.0 


0.8 


0.5 


3.15 


3.87 


4.32 


1.00 




2.5 




0.5 


0.33 


3.15 


3.60 


3.90 


2.2 




1.2 


2.43 


3.51 


4.59 


1.20 


1.9 




1.3 




0.30 


2.52 


2.79 


3.06 


°2.7 


0.8 


0.5 


2.88 


3.60 


4.05 


1.00 




2.0 




0.5 


0.33 


2.70 


3.15 


3.45 


2.2 




1.0 


2.43 


3.33 


4.23 


1.20 


2.1 




1.4 




0.30 


2.65 


2.92 


3.19 


°2.7 


0.8 


0.5 


2.88 


3.60 


4.05 


1.00 




2.2 




0.5 


0.33 


2.88 


3.33 


3.63 


2.6 




1.2 


2.79 


3.87 


4.95 


1.35 


3.2 




2.1 




0.33 


3.60 


3.90 


4.19 


5.5 




2.5 


5.40 


7.65 


9.90 


1.35 


3.5 




2.3 




0.33 


3.82 


4.12 


4.42 



240 



Municipal Electrical Service 



Municipal Electrical 
RATES AND TYPICAL BILLS 

in effect 

Rates are quoted on a monthly basis and 
and a minimum 



Municipality 



•2 * 



2& 



Residential service 






Rate per kwh 
for 



E"o 



8 


o 
o 


Ijs 


XJ3 

V > 
£.1 


i 


i 


1.2 


0.7 


1.8 


1.1 


1.6 


0.9 


1.5 


0.8 


1.2 


0.7 


1.5 


0.8 


3.5 




1.2 


0.7 


1.6 


1.0 


1.2 


0.7 


1.2 


0.7 


1.4 


0.8 


1.5 


0.9 


1.3 


0.7 


1.1 


0.7 



■a* 

"O— > 

3-2 



Net monthly bill 
for 



Welland 

Wellesley 

Wellington 

West Ferris Twp 
West Lome 

Weston 

West port 

Wheatley 

Whitby 

t White River. . . . 

Wiarton 

Williamsburg. . . 

Winchester 

Windermere .... 
Windsor 

Wingham 

Woodbridge. . . . 

Woodstock 

Woodville 

Wyoming 

York Twp 

Zurich 



No. 
41 
44 
43 
37 
45 

37 
38 
45 
36 
60 



42 



41 



45 



i 

1.67 
1.67 
1.67 
1.67 
1.67 

1.67 
1.67 
1.67 
1.67 
1.67 

1.67 

1.67 
1.67 
1.67 

1.67 
1.67 
1.67 
1.67 
1.67 

1.67 



No. 
60 
60 
50 
50 
50 

50 
50 
60 
50 
50 

50 
60 
60 
50 
50 

50 
50 
50 
60 
50 

50 
60 



I 

2.4 

3.3 

2.4 

3.6 

3.2 

3.0 
2.4 
3.3 
3.0 
7.0 

2.4 
2.0 
2.5 
3.2 
2.4 

2.4 
2.8 
3.0 
3.8 
2.6 

2.2 
3.7 



i 

1.1 
1.3 
1.0 
1.5 
1.3 

1.2 
1.0 
1.2 
1.2 
1.6 

1.0 
0.8 
1.2 
1.4 
1.0 

1.0 
1.1 
1.2 
1.2 

1.0 

1.0 
1.2 



$ 


1.69 


2.25 


1.62 


2.43 


2.16 


2.02 


1.62 


2.21 


2.02 


4.72 


1.62 


1.37 


1.78 


2.16 


1.62 


1.62 


1.89 


2.02 


2.48 


1.75 


1.48 


2.43 



$ 

3.67 
4.59 
3.55 
5.35 
4.72 

4.41 
3.55 
4.37 
4.41 
10.17 

3.55 
2.81 
3.94 
4.77 
3.55 

3.55 
4.14 
4.45 
4.64 

3.82 

3.28 
4.59 



$ 
5.65 
6.93 
4.81 
7.33 
6.34 

5.85 
4.81 
6.53 
5.85 
13.05 

4.81 
4.25 
6.10 
6.57 
4.81 

4.81 
5.58 
6.07 
6.80 
5.08 

4.54 
6.75 



t Local system 

NOTES 

Service Charges 

a 33£ per month per service when the permanently installed appliance load is under 2,000 watts and 

66 i per month when 2,000 watts or more, 
b Demand rate 8.50 per 100 watts, minimum 500. 
c Minimum demand charge 250. 

■ House Heating 

Applicable where electric energy is used to heat an entire dwelling or a portion of a dwelling in excess 
of 25% of the floor area. 



Statement C 



241 



Utilities and Local Systems 
FOR ELECTRICAL SERVICE 
December 31, 1960 

are subject to 10% prompt payment discount 
monthly charge 



Commercial service 


Industrial power service 


Demand rate 




















per 100 watts 




















5.0 cents, 
minimum 50 cents 


Net monthly bill 


* 

^ 




Energy rate per kwh 




Net monthly bill 




for use of 
1 kw of demand 


u 

a 




for use of 
each kw of demand 




for use of 
1 kw of dems 




Energy rate per 


md 


kwh for use of 






<v 














each kw of demand 






•O 
c 

E 

<v 

Q 


















10 

u 
















to 








tO 

3 
O 

to « 

■a 8 


to 

3 
O 

11 


3 

.J. o 
3-2 


to 

a 

3 
O 

o 


at 
c 

3 
O 

8 


to 

3 
O 

J3 

© 
o 


to 
U 

3 


3 
O 

is 


u 

3 

-w O 

£° 


05 

3 
O 

II 


3 

33 


to 

3 
O 

8 


2 

3 


JC 






C 

3 
O 

8 


i 


i 


i 


$ 


$ 


$ 


$ 


i 


* 


* 


* 


* 


$ 


$ 


$ 


2.1 




1.0 


2.34 


3.24 


4.14 


1.20 


1.9 




1.3 




0.30 


2.52 


2.79 


3.06 


2.8 




1.2 


2.97 


4.05 


5.13 


1.35 


2.0 




1.3 




0.33 


2.70 


3.00 


3.29 


°2.3 


0.8 


0.5 


2.52 


3.24 


3.69 


1.00 




1.8 




0.5 


0.33 


2.52 


2.97 


3.27 


°3.0 


0.8 


0.5 


3.15 


3.87 


4.32 


1.00 




2.0 




0.5 


0.33 


2.70 


3.15 


3.45 


°2.8 


0.8 


0.5 


2.97 


3.69 


4.14 


1.00 




2.3 




0.5 


0.33 


2.97 


3.42 


3.72 


°2.2 


0.8 


0.5 


2.43 


3.15 


3.60 


1.00 




1.7 




0.5 


0.33 


2.43 


2.88 


3.18 


°2.2 


0.8 


0.5 


2.43 


3.15 


3.60 


1.00 




1.7 




0.5 


0.33 


2.43 


2.88 


3.18 


2.9 




1.2 


3.06 


4.14 


5.22 


1.35 


2.5 




1.6 




0.33 


3.06 


3.36 


3.65 


°2.3 


0.8 


0.5 


2.52 


3.24 


3.69 


1.00 




1.5 




0.5 


0.33 


2.25 


2.70 


3.00 


°5.8 


0.8 


0.5 


5.67 


6.39 


6.84 


1.00 




5.1 




0.5 


0.33 


5.49 


5.94 


6.24 


°2.2 


0.8 


0.5 


2.43 


3.15 


3.60 


1.00 




1.7 




0.5 


0.33 


2.43 


2.88 


3.18 


2.0 




0.8 


2.25 


2.97 


3.69 


1.35 


3.1 




2.0 




0.33 


3.51 


3.81 


4.10 


2.0 




1.1 


2.25 


3.24 


4.23 


1.35 


2.0 




1.3 




0.33 


2.70 


3.00 


3.29 


°2.8 


0.8 


0.5 


2.97 


3.69 


4.14 


1.00 




2.3 




0.5 


0.33 


2.97 


3.42 


3.72 


°2.2 


0.8 


0.5 


2.43 


3.15 


3.60 


1.00 




1.5 




0.5 


0.33 


2.25 


2.70 


3.00 


°2.1 


0.8 


0.5 


2.34 


3.06 


3.51 


1.00 




1.6 




0.5 


0.33 


2.34 


2.79 


3.09 


°2.3 


0.8 


0.5 


2.52 


3.24 


3.69 


1.00 




1.8 




0.5 


0.33 


2.52 


2.97 


3.27 


°2.2 


0.8 


0.5 


2.43 


3.15 


3.60 


1.00 




1.5 




0.5 


0.33 


2.25 


2.70 


3.00 


3.2 




1.2 


3.33 


4.41 


5.49 


1.35 


2.5 




1.6 




0.33 


3.06 


3.36 


3.65 


°2.4 


0.8 


0.5 


2.61 


3.33 


3.78 


1.00 




1.9 




0.5 


0.33 


2.61 


3.06 


3.36 


°1.7 


0.8 


0.5 


1.98 


2.70 


3.15 


1.00 




1.2 




0.5 


0.33 


1.98 


2.43 


2.73 


3.4 




0.9 


3.51 


4.32 


5.13 


1.35 


3.1 




2.0 




0.33 


3.51 


3.81 


4.10 



NOTES 
Special Rates or Discounts 

*First 60 kwh of monthly consumption at 2. Off, second 60 kwh and all kwh in excess of 1,000 at l.Off. 
**Flat-rate water-heater service — Toronto: 

System-owned — First 400 watts $2.90 per month. 

Each 100 watts additional 40^ per month, plus a monthly charge for larger tank 
sizes as follows: 

30ff for 1,000-watt and 1,200-watt heaters. 
40?f for 1,500-watt heaters. 
50^ for 2,000-watt and 2,500-watt heaters. 
55ff for heaters 3,000 watts and over. 
Customer-owned — First 400 watts $1.98 per month. 

Each 100 watts additional 40^ per month. 
Commercial customers with a connected load of under 5 kilowatts billed at residential rates. 
§Farm customers billed at standard rural rates. 
§§Farm customers billed at special rates. 



242 



Municipal Electrical Service 



Municipal Electrical 
GROSS MONTHLY ENERGY RATES 

Subject to 10% 





Schedule 


Element 
rating 


25 


26 


27 


28 


29 


30 


31 


32 


33 


34 


35 


36 


37 


38 


39 


40 


41 


watts 


$ 


$ 


$ 


$ 


$ 


$ 


$ 


$ 


$ 


$ 


$ 


$ 


$ 


$ 


$ 


$ 


$ 


400 


1.00 


1.04 


1.08 


1.12 


1.16 


1.20 


1.24 


1.28 


1.32 


1.36 


1.40 


1.44 


1.48 


1.52 


1.56 


1.60 


1.64 


450 


1.12 


1.17 


1.21 


1.26 


1.30 


1.36 


1.40 


1.44 


1.49 


1.53 


1.58 


1.62 


1.67 


1.71 


1.76 


1.80 


1.84 


500 


1.25 


1.30 


1.35 


1.40 


1.45 


1.50 


1.55 


1.60 


1.65 


1.70 


1.75 


1.80 


1.85 


1.90 


1.95 


2.00 


2.05 


550 


1.38 


1.43 


1.49 


1.54 


1.60 


1.66 


1.70 


1.76 


1.81 


1.87 


1.92 


1.98 


2.03 


2.09 


2.14 


2.20 


2.26 


600 


1.50 


1.56 


1.62 


1.68 


1.74 


1.80 


1.86 


1.92 


1.98 


2.04 


2.10 


2.16 


2.22 


2.28 


2.34 


2.40 


2.46 


650 


1.59 


1.66 


1.71 


1.78 


1.84 


1.91 


1.97 


2.03 


2.10 


2.16 


2.22 


2.29 


2.36 


2.41 


2.48 


2.54 


2.61 


700 


1.68 


1.74 


1.81 


1.88 


1.94 


2.01 


2.08 


2.14 


2.21 


2.28 


2.34 


2.41 


2.48 


2.54 


2.61 


2.68 


2.74 


750 


1.78 


1.84 


1.91 


1.99 


2.06 


2.12 


2.20 


2.27 


2.34 


2.41 


2.48 


2.56 


2.62 


2.69 


2.77 


2.83 


2.91 


800 


1.86 


1.93 


2.00 


2.08 


2.16 


2.22 


2.30 


2.38 


2.44 


2.52 


2.60 


2.67 


2.74 


2.82 


2.90 


2.97 


3.04 


850 


1.94 


2.02 


2.10 


2.18 


2.26 


2.33 


2.41 


2.49 


2.57 


2.64 


2.72 


2.80 


2.88 


2.96 


3.03 


3.11 


3.19 


900 


2.04 


2.12 


2.20 


2.29 


2.37 


2.44 


2.53 


2.61 


2.69 


2.78 


2.86 


2.93 


3.02 


3.10 


3.18 


3.27 


3.34 


950 


2.13 


2.22 


2.30 


2.39 


2.48 


2.56 


2.64 


2.73 


2.81 


2.90 


2.99 


3.07 


3.16 


3.24 


3.33 


3.41 


3.50 


1,000 


2.22 


2.31 


2.40 


2.49 


2.58 


2.67 


2.76 


2.84 


2.93 


3.02 


3.11 


3.20 


3.29 


3.38 


3.47 


3.56 


3.64 



Note: Gross monthly rates for all element sizes over 1,000 watts are calculated as follows: 

Element rating 



Rate for 1,000-watt element X 






1,000 



Statement C 



243 



Utilities and Local Systems 

FOR FLAT-RATE WATER-HEATING 

prompt payment discount 



Number 



42 


43 


44 


45 


46 


47 


48 


49 


50 


51 


52 


53 


54 


55 


56 


57 


58 


59 


60 


$ 


$ 


$ 


$ 


$ 


$ 


$ 


$ 


$ 


$ 


$ 


$ 


$ 


$ 


$ 


$ 


$ 


$ 


$ 


1.68 


1.72 


1.76 


1.80 


1.84 


1.88 


1.92 


1.96 


2.00 


2.04 


2.08 


2.12 


2.16 


2.20 


2.24 


2.28 


2.32 


2.36 


2.40 


1.89 


1.93 


1.98 


2.02 


2.07 


2.11 


2.16 


2.20 


2.26 


2.29 


2.34 


2.38 


2.42 


2.47 


2.52 


2.56 


2.60 


2.66 


2.72 


2.10 


2.15 


2.20 


2.25 


2.30 


2.35 


2.40 


2.45 


2.50 


2.55 


2.60 


2.65 


2.70 


2.75 


2.80 


2.85 


2.90 


2.95 


3.00 


2.31 


2.37 


2.42 


2.48 


2.53 


2.59 


2.64 


2.70 


2.76 


2.81 


2.86 


2.92 


2.98 


3.03 


3.08 


3.14 


3.20 


3.26 


3.32 


2.52 


2.58 


2.64 


2.70 


2.76 


2.82 


2.88 


2.94 


3.00 


3.06 


3.12 


3.18 


3.24 


3.30 


3.36 


3.42 


3.48 


3.54 


3.60 


2.67 


2.73 


2.80 


2.86 


2.92 


2.99 


3.06 


3.11 


3.18 


3.25 


3.32 


3.37 


3.42 


3.49 


3.56 


3.62 


3.68 


3.75 


3.82 


2.81 


2.88 


2.94 


3.01 


3.08 


3.14 


3.21 


3.28 


3.34 


3.42 


3.48 


3.55 


3.62 


3.69 


3.76 


3.82 


3.88 


3.95 


4.02 


2.98 


3.04 


3.12 


3.19 


3.26 


3.33 


3.40 


3.48 


3.54 


3.62 


3.68 


3.75 


3.82 


3.90 


3.98 


4.05 


4.12 


4.18 


4.24 


3.12 


3.19 


3.27 


3.34 


3.41 


3.49 


3.57 


3.63 


3.71 


3.79 


3.86 


3.93 


4.00 


4.08 


4.16 


4.24 


4.32 


4.38 


4.44 


3.27 


3.34 


3.42 


3.50 


3.58 


3.66 


3.73 


3.81 


3.90 


3.96 


4.04 


4.12 


4.20 


4.28 


4.36 


4.44 


4.52 


4.59 


4.66 


3.42 


3.51 


3.59 


3.67 


3.76 


3.83 


3.91 


4.00 


4.08 


4.16 


4.24 


4.32 


4.40 


4.49 


4.58 


4.66 


4.74 


4.81 


4.88 


3.59 


3.67 


3.76 


3.84 


3.92 


4.01 


4.10 


4.18 


4.27 


-1.35 


4.44 


4.52 


4.60 


4.69 


4.78 


4.87 


4.96 


5.04 


5.12 


3.73 


3.82 


3.91 


4.00 


4.09 


4.18 


4.27 


4.36 


4.44 


4.53 


4.62 


4.71 


4.80 


4.89 


4.98 


5.07 


5.16 


5.25 


5.34 



244 



Municipal Electrical Service 



Forty Major Municipal 
(Arranged in descending order 

CUSTOMERS, REVENUE, 
for the Year Ended 



Municipality 



Total 
revenue 
including 

street 
lighting 



Total 

consumption 

including 

street 

lighting 



Residential service 
(including flat-rate water-heaters) 



Revenue 



Consumption 



Cus- 
tomers 



I E 

1 1 

C u 

o v 



Av- 
erage 
cost 



Toronto (including Leaside) 

Hamilton 

^Ottawa (including Eastview and 

Rockcliffe Park) 

#Sarnia 

North York Twp 



^.Scarborough Twp 

#Etobicoke Twp. (including 

Thistletown) 

^Windsor 

London 

#Oshawa 



#York Twp. . . . 
Kitchener . . . . 

^Toronto Twp. 
Brantford 
Kingston. . . . 



St. Catharines. 
Port Arthur . . . 
Fort William. . 
Peterborough . 



#East York Twp 

#Guelph 

Oakville- <#Trafalgar. 

^>New Toronto 

# Burlington 



Gait 

Belleville . . 

Merritton. . 

^Woodstock. 

Chatham . . 



#>Niagara Falls. . 
#Trenton 

Barrie 

Waterloo 

Stamford Twp. 



Stratford . . . 
St. Thomas. 
North Bay. 
Brockville. . 
Orillia 



$ 
37,251.067 
15,750,820 

10,149,428 
6,054,562 
9.445,822 

7,310,532 

6,736,647 
4,444,164 
4,015,853 
2,855,956 

3,316,025 
3,748,456 
3,024,299 
2,185,040 
2,026,083 

2,383,924 
1,777,331 
1.697,212 
1.985,551 
Sudbury 2,444,115 



1,878,757 
1,860,520 
1,813.305 
1,259.277 
1,927,526 

1,267,929 
934,494 
842,779 
977,443 

1,459,215 

1,001,916 
667,808 
851,590 
882,416 

1,050,853 

905,912 
857,329 
909,260 
717,827 
739,758 



kwh 
3,137,028,215 
1,909,600,091 

1,052,467,797 
907,989,540 
804,121,838 

620,943,248 

587,797,049 
372,328,877 
361,865,107 
330,122,169 

327,199,369 
320,199,399 
299,053,588 
204,425,520 
199,636,866 

199,199,488 
195,925,950 
194,401,047 
187,587,929 
184,113,918 

175,386,737 
168,291.177 
161,258,445 
148,420,770 
137,918,581 

107,946,784 

106,948,677 

105,436,845 

89,273,492 

89,159,244 

84,168,698 
83,751,371 
82,891,823 
77,382,248 
75,025,921 

74,793,546 
74,026,390 
73,941.296 
73.074,809 
70,993,208 



11,753,682 
4,083,296 

4,404,803 

745,006 

5,215,014 

4,212,528 

3,669,098 

1,408,046 

1,501,625 

979,496 

2,029,551 

1,513,662 

1,155,504 

898,929 

851,280 

779,145 
718,651 
747,584 
883,187 
1,444,257 

1.217,245 
797,344 
818,540 
225,068 

1,256,417 

509,841 
457,037 
109,170 
418,067 
423,517 

380,168 
210,183 
407,723 
395,652 
587,156 

426,606 
374,790 
461,843 
287,206 
259,412 



kwh 
937,716,480 
354,023.802 

581,874,068 

55,923,697 

479,034,282 

359,763,818 

311,309,537 
125,232,323 
121.856,121 
116.597.560 

212.262,622 

132,063,086 

102,675,231 

79,600,305 

93.027,078 

58,285,283 
85,673,732 
96,082,799 
84,046,544 
124,278,030 

117,481,857 
68,484,628 
66,450,004 
20,610,208 
92,186,015 

42,830,590 
56,616,783 
8,777,283 
37,298,668 
23,652,169 

30,130,765 
23,551,276 
40,343.663 
38,890,633 
45,934,303 

37,437,191 
30,126,086 
39,938,924 
28,252,255 
26,650,044 



No. 
175,156 

70,371 

76,590 
14,443 
72,372 

56,934 

46,495 
34,335 
29,693 
17,359 

38,670 
21,244 
14,384 
15,140 
13,208 

12,218 
11,992 
11,976 
13,099 
20,011 

21,802 
10,946 
9,851 
3,746 
12,792 

7,914 
8,435 
1,787 
6,296 
8,050 

6,889 

3,744 
6,038 
5,885 
8,253 

6,164 
6,201 
6.273 
5.124 
4,620 



kwh 
446 
419 

633 
323 

552 

527 

558 
304 
342 
560 

457 
518 
595 
438 
587 

398 
595 
669 

535 
518 

449 
521 
562 
458 
601 

451 
559 
409 
494 
245 

364 

532 
557 
551 
464 

506 
405 
531 
459 
481 



For explanation of symbols see page 264. 



Statement D 



245 



Electrical Utilities 
of total consumption) 

AND CONSUMPTION 
December 31. 1960 



(incl 


Commercial service 
uding flat-rate water-heaters) 






Industrial 


POWER SERVICE 












£ «3 


Av- 








3:5 


c fc 


Av- 








•2 E 


erage 








"S §*8 


■9 E 


erage 






Cus- 


hly 
mp 

JStO 


cost 






Cus- 




hly 
isto 


cost 


Revenue 


Consumption 


tomers 


Mont 
consu 

per ci 


per 
kwh 


Revenue 


Consumption 


tomers 


Averj 

tomei 
loads 


Mont 
consu 
per ci 


per 
kwh 


$ 


kwh 


No. 


kwh 


i 


% 


kwh 


No. 


kw 


kwh 


i 


9,259.394 


629.701.930 


26,802 


1,958 


1.47 


15,301.553 


1,521,639.865 


6,998 


411,561 


18,120 


1.01 


2.232.234 


180,089.452 


8,439 


1,778 


1.24 


9,085,031 


1,358,254,659 


1,401 


265,679 


80.791 


0.67 


4.933,466 


415,216.004 


10,838 


3,193 


1.19 


473,813 


43,063,870 


201 


15.924 


17,854 


1.10 


360.341 


24.218.109 


806 


2,504 


1.49 


4,879,498 


825.395,334 


170 


105.769 


404,606 


0.59 


2,412.287 


158,004.178 


6,144 


2,143 


1.53 


1,608,091 


154,744,758 


1,211 


53,599 


10,649 


1.04 


1,389,214 


103,496.378 


2,566 


3,361 


1.34 


1.453,237 


145,686,252 


315 


42,104 


38,541 


1.00 


1.003,996 


70,056.709 


1,876 


3.112 


1.43 


1,825,605 


196,591,035 


867 


54,944 


18,896 


0.93 


855,446 


65.276.683 


2,047 


2,657 


1.31 


1,879,491 


172,216,246 


760 


65.467 


18,883 


1.09 


1,044,007 


78.046,850 


2,983 


2,180 


1.34 


1,322,275 


155,845,821 


431 


43.222 


30,133 


0.85 


408,809 


34,233,406 


1,625 


1,756 


1.19 


1,359,260 


174,066,763 


271 


43,219 


53,526 


0.78 


497,346 


40,545,018 


1,228 


2.751 


1.23 


649,327 


68.827,149 


525 


23,053 


10.925 


0.94 


698,580 


44,720,135 


1,714 


2,174 


1.56 


1,419,088 


138,210,898 


366 


39,968 


31,469 


1.03 


374,713 


26,261,811 


578 


3,786 


1.43 


1,409,499 


167,561,038 


168 


35,622 


83.116 


0.84 


373,591 


30,299,734 


1,570 


1,608 


1.23 


848,524 


91,453,761 


299 


30,558 


25,489 


0.93 


706,999 


61,163,191 


2,055 


2,480 


1.16 


402,304 


43,315,397 


234 


13.728 


15,426 


0.93 


474,871 


27,655,408 


1,633 


1.411 


1.72 


1,058,670 


110,172,797 


254 


30,951 


36,146 


0.96 


413,937 


38,358,934 


1,622 


2,065 


1.08 


581,859 


68.750.884 


59 


24,243 


43,077 


0.85 


370,160 


36,883,798 


1,522 


2.019 


1.00 


492,246 


58.052.450 


221 


20,525 


21,890 


0.85 


435,597 


27,689,438 


1,410 


1.636 


1.57 


594,610 


72,717,747 


248 


20,189 


24,435 


0.82 


696,722 


41,162,038 


1,962 


1,748 


1.69 


200,014 


15,840,914 


243 


6,329 


5.432 


1.26 


291,546 


22,889,541 


878 


2,329 


1.27 


297,101 


31,812,739 


89 


9.788 


17,913 


0.93 


317.340 


22,250,038 


1,009 


1,838 


1.43 


682,845 


75,203,631 


148 


20.342 


42,344 


0.91 


258,532 


14,013,271 


792 


1,474 


1.84 


706,290 


79,726,318 


197 


17.066 


33,725 


0.89 


134,040 


10,443,481 


269 


3,235 


1.28 


881,876 


116,630,481 


37 


25.140 


262,681 


0.76 


297,270 


17,605,949 


613 


2,393 


1.69 


357,986 


27,481,337 


142 


9,499 


16,128 


1.30 


189,897 


10,958,086 


819 


1,115 


1.73 


511,202 


52,098,108 


214 


17,032 


20,287 


0.98 


248,106 


21.348.889 


1,116 


1,594 


1.16 


202,733 


27,618,035 


164 


8,252 


14,034 


0.73 


72,680 


4,052,393 


191 


1,768 


1.79 


651,627 


92,303,009 


23 


16,570 


334,431 


0.71 


138,690 


10,068,614 


360 


2,331 


1.38 


381,975 


39,881,910 


142 


11,907 


23,405 


0.96 


432,165 


20,812,443 


1,204 


1,441 


2.08 


524,899 


41,930,632 


255 


14,568 


13,703 


1.25 


336,781 


27,702,661 


543 


4,251 


1.22 


239,052 


24,283,672 


48 


7,413 


42,159 


0.98 


85.481 


7,427,900 


249 


2,016 


1.15 


354,242 


51,972,275 


85 


10,918 


50,953 


0.68 


218,108 


15.444,631 


816 


1,577 


1.41 


211,269 


26,349,729 


107 


8,084 


20,522 


0.80 


183,416 


11,680.796 


467 


2,084 


1.57 


261,140 


24,993,619 


93 


7.295 


22,396 


1.04 


204,583 


9,684,138 


576 


1,401 


2.11 


211,978 


17,706,440 


102 


6.813 


14,466 


1.20 


188,040 


12,541,650 


655 


1,596 


1.50 


246,019 


22.760,933 


159 


8,428 


11,929 


1.08 


180,226 


13,146,585 


722 


1,517 


1.37 


281,112 


29,965,679 


110 


9,151 


22,701 


0.94 


291,271 


21,276,258 


1,087 


1,631 


1.37 


128,517 


11,496,314 


139 


3,825 


6,892 


1.12 


126,973 


9,858,493 


662 


1,241 


1.29 


284.004 


34,217,917 


93 


9,659 


30,661 


0.83 


162,324 


12,482,211 


660 


1,576 


1.30 


300.976 


31.194,513 


141 


11,804 


18,436 


0.96 



246 



Municipal Electrical Service 



Municipal Electrical 

CUSTOMERS, REVENUE, 

for the Year Ended 



Municipality 



Popula- 
tion 



Total 
customers 



Peak 
load 
Decem- 
ber 
1960 



Residential service 
(including flat-rate water-heaters) 



Revenue 



Consumption 



Cus- 
tomers 



I § 

C i- 

o V 

<J o. 



♦Acton 

♦Ailsa Craig 

♦Ajax 

♦Alexandria 

♦Alfred 

Alliston 

♦Almonte 

Alvinston 

♦Amherstburg 

Ancaster Twp. (including 
Ancaster) 

Apple Hill 

♦Arkona 

♦Arnprior 

♦Arthur 

♦Athens 

♦Atikokan Twp 

♦Aurora 

♦Avonmore 

♦Aylmer 

Ayr 

♦ Baden 

<^tBala 

Bancroft 

Barrie 

♦ Barry's Bay 

Bath 

♦ Beachville 

Beamsville 

♦fBeardmore 

Beaverton 

♦ Beeton 

♦ Belle River 

Belleville 

♦ Blenheim 

♦ tBlind River 

♦ Bloomfield 

♦ Blyth 

Bobcaygeon 

♦ Bolton 

Bothwell 



No. 
4,336 

541 
7,937 
2,451 

915 

2,904 

3,295 

651 

4,344 

12,903 

400 

480 

5,502 

1,241 

981 

7,456 
7,124 
250 
4,734 
1,035 

882 

*495 

2,497 

21,271 

1,468 

723 

820 

2,387 

1,125 

1,159 

783 

1,847 

29.070 

3,045 

4,027 

720 

743 

1,197 

1,921 



o. 


kw 


1,306 


4,102 


222 


364 


2,166 


5.961 


867 


2,025 


299 


496 


1,090 


2,082 


1,085 


1,932 


323 


294 


1,451 


3,520 


1,086 


2,446 


117 


108 


200 


387 


1,751 


4,317 


496 


812 


350 


491 


1.927 


4,061 


2,631 


5,745 


114 


194 


1,561 


4,636 


372 


772 


281 


891 


796 


316 


791 


1,439 


6,961 


18.034 


412 


384 


246 


391 


290 


2,184 


855 


1,627 


321 


478 


556 


1,182 


314 


548 


690 


717 


9,715 


24,439 


1.125 


1,680 


1,202 


2,096 


313 


516 


326 


645 


711 


750 


654 


1,286 


319 


457 



$ 

87,667 
10,280 
134,942 
40,512 
14,293 

56,204 

52,979 

7,564 

87,928 

102,079 

4,326 
12,853 
91,793 
23.993 
13,236 

164,702 

123.277 

7.395 

73.077 

19,055 

16,922 
29.482 
49.979 
407,723 
13.631 

14,978 
16,496 
48.667 
19,730 
25,337 

16,970 
28,506 
457,037 
37.616 
82.790 

11.837 
15.178 
28.483 
52,869 
8,998 



kwh 
7,303,400 
775.340 
10,519.245 
3,953.125 
1.009,355 

4,950,103 

5,636,921 

420,260 

7.781,641 

7,831,336 

263,020 

922,618 

9,324,874 

1,991,870 

1,375.497 

13.041,234 

11,310,208 

430.980 

7.761.217 

1.671,536 

1.456.390 

1.147,616 

3,427,720 

40.343.663 

915.050 

1.062.283 
1.429.900 
4.188.072 
1,165.750 
1,964,091 

1.217,519 

1,512,179 

56,616,783 

2,575,724 
5,254,132 

1.276.123 
1.234.620 
1.761,635 
3.769,401 
687.862 



No. 

1,209 
201 

1,990 
786 
273 

896 
1.005 

253 
1.301 

1,005 

99 

188 

1,622 

443 

333 

1.780 
2.389 

103 
1.420 

307 

266 
712 
655 
6.038 
383 

221 
277 
731 
247 
464 

291 

628 

8.435 

1,001 

1,015 

294 
290 
591 
617 
246 



kwh 
503 
321 
441 
419 
308 

460 
467 
138 
498 

649 

221 
409 
479 
375 
344 

611 
395 
349 
455 
454 

456 
134 
436 
557 
199 

401 
430 
477 
393 
353 

349 
201 
559 
214 
431 

362 
355 
248 
509 
233 



For explanation of symbols see page 264. 



Statement D 



247 



Utilities and Local Systems 
AND CONSUMPTION 
December 31, 1960 



Commercial service 
(including flat-rate water-heaters) 




Industrial power 


SERVICE 










c ir, 


Av- 








3S 


c !^ 


Av- 


Revenue 


Consumption 


Cus- 
tomers 


Monthly 
consumptio 
per custome 


erage 
cost 
per 
kwh 


Revenue 


Consumption 


Cus- 
tomers 


Average of 
tomers'mon 
loads billed 


Monthly 
consumptio 
per custome 


erage 
cost 
per 
kwh 


$ 


kwh 


No. 


kwh 


i 


$ 


kwh 


No. 


kw 


kwh 


i 


24,374 


1,420,581 


67 


1,767 


1.72 


97,974 


7,757,012 


30 


2.583 


21,547 


1.26 


3,402 


191,170 


17 


937 


1.78 


4,042 


189,296 


4 


119 


3,944 


2.14 


32,814 


2,181,530 


107 


1,699 


1.50 


157,816 


13,813,193 


69 


4,430 


16,683 


1.14 


18,387 


1,289,591 


63 


1,706 


1.43 


28,075 


2,362,265 


18 


790 


10,936 


1.19 


3,484 


186,901 


17 


916 


1.86 


7,285 


444,868 


9 


251 


4.119 


1.64 


27,099 


1,565,223 


163 


800 


1.73 


22,983 


2,140,278 


31 


713 


5,753 


1.07 


11,957 


901,794 


54 


1,392 


1.33 


30,734 


3,383,708 


26 


1,100 


10,845 


0.91 


6,692 


318,770 


62 


428 


2.10 


2,151 


94,105 


8 


67 


980 


2.29 


35,644 


2,273,305 


117 


1,619 


1.57 


63,712 


5,748,590 


33 


1,725 


14,517 


1.11 


18,598 


762,736 


71 


895 


2.44 


5,951 


394,483 


10 


160 


3,287 


1.51 


1,262 


57,180 
141,791 


18 
10 


265 
1,182 


2.21 
1.57 














2,222 


2,914 


139,520 


2 


76 


5,813 


2.09 


33,466 


2,489,226 


97 


2,139 


1.34 


60,061 


5,595,813 


32 


1,992 


14,572 


1.07 


7,556 


400,934 


38 


879 


1.88 


5,919 


351,690 


15 


225 


1,954 


1.68 


2,733 


201,110 


15 


1,117 


1.36 


869 


55,200 


2 


45 


2,300 


1.57 


54,401 


3,498,394 


115 


2,535 


1.56 


44,783 


5,021,061 


32 


1,089 


13,076 


0.89 


51,488 


3,482,219 


197 


1,473 


1.48 


89,567 


7,792,330 


45 


2,575 


14,430 


1.15 


1,983 


100,230 


10 


835 


1.98 


256 


5,100 


1 


15 


425 


5.01 


36,926 


2,776,070 


108 


2,142 


1.33 


69,047 


6,184,441 


33 


2,401 


15,617 


1.12 


9,169 


548,740 


52 


879 


1.67 


8,724 


340,066 


13 


329 


2,180 


2.57 


2,575 


180,113 


10 


1,501 


1.43 


17,593 


1,229,730 


5 


579 


20.496 


1.43 


12,703 


528,637 


78 


565 


2.40 


1,019 


64,382 


6 


41 


894 


1.58 


29,060 


1,365,223 


122 


933 


2.13 


10,826 


752,491 


14 


397 


4,479 


1.44 


218,108 


15,444,631 


816 


1,577 


1.41 


211,269 


26,349,729 


107 


8,084 


20,522 


0.80 


5,857 


383,540 


26 


1,229 


1.53 


970 


76,670 


3 


26 


2,130 


1.27 


3,438 


142,930 


23 


518 


2.41 


839 


67,940 


2 


19 


2,831 


1.23 


2,146 


117.553 


11 


891 


1.83 


93,181 


12,655,660 


2 


2,062 


527,319 


0.74 


19,178 


1.094,106 


111 


821 


1.75 


10,908 


623,860 


13 


372 


3,999 


1.75 


14,435 


770,367 


72 


892 


1.87 


192 


2,680 


2 


10 


112 


7.18 


14,163 


890,310 


80 


927 


1.59 


25,252 


1,944,492 


12 


830 


13,503 


1.30 


2,997 


141,090 


15 


784 


2.12 


5.968 


329,990 


8 


146 


3,437 


1.81 


15,402 


792,881 


57 


1,159 


1.94 


3,532 


221,459 


5 


101 


3,691 


1.60 


248,106 


21,348.889 


1,116 


1,594 


1.16 


202,733 


27,618,035 


164 


8,252 


14,034 


0.73 


29,546 


1,717,906 


98 


1,461 


1.72 


22,837 


1,290,420 


26 


774 


4,136 


1.77 


42,330 


2,258,203 


178 


1,078 


1.87 


17,208 


1,318,833 


9 


444 


8,792 


1.30 


2,847 


185,013 


14 


1,101 


1.54 


1,267 


45,393 


5 


84 


757 


2.79 


5,344 


310,713 


29 


893 


1.72 


13,172 


1,103,765 


7 


325 


13,140 


1.19 


14,693 


694,692 


111 


522 


2.12 


7,294 


324,574 


9 


257 


3,005 


2.25 


8,241 


418,200 


24 


1,452 


1.97 


5,701 


318,555 


13 


196 


2,042 


1.79 


7,671 


531,242 


63 


703 


1.44 


4,796 


117,425 


10 


194 


979 


4.08 



248 



Municipal Electrical Service 



Municipal Electrical 

CUSTOMERS, REVENUE, 

for the Year Ended 



Municipality 



Popula- 
tion 



Total 
customers 



Peak 
load 
Decern 
ber 
1960 



Residential service 
(including flat-rate water-heaters) 



Revenue 



Consumption 



Cus- 
tomers 



#Bowmanville. . 
Bracebridge. . . 

# Bradford 

^Braeside 

#> Brampton 

Brantford 

#Brantford Twp 

# Brechin 

<f> Bridgeport. . . . 
<$>Brigden 

# Brighton 

Brockville 

Brussels 

#Burford 

Burgessville. . . 

#Burk's Falls. . . 
#Burlington. . . . 
<#>Cache Bay. . . . 

Caledonia 

#>Campbellford. 

Campbellville. 

Cannington. . . 

Capreol 

^Cardinal 

^Carleton Place 

#Casselman. . . . 

^Cayuga 

#Chalk River. . 

Chapleau Twp. 

Chatham 

#Chatsworth. . . 

Chesley 

Chesterville. . . 

Chippawa. . . . 
^Clifford 

^-Clinton 

♦tCobalt 

'fCobden 

<#Cobourg 

Cochrane 



No. 

7.308 

2,906 

2,395 

563 

17,385 

53,616 
7,473 

259 
1,674 

491 

2,345 
17,124 

830 
1,029 

245 

884 
44,709 

896 
2,265 
3,373 

364 
1,059 
2.730 
1,972 
4,688 

1,301 

920 

1,052 

3,696 

29,271 

399 
1,635 
1.248 
3.027 

557 

3.107 
2,090 
915 
9,445 
4,368 



No. 

2,446 

1,133 

836 

161 

5,392 

17,009 

2,195 

99 

460 

215 

981 
5,879 
385 
427 
100 

341 

13,547 

201 

788 

1.346 

90 

450 

953 

663 

1,712 

379 
371 
290 
959 
9,509 

165 

717 

457 

1.035 

227 

1.232 

771 

403 

3.387 

1,299 



kw 
6,164 
89 
1.877 
1,770 
14,307 

46,020 

5.634 

152 

932 

248 

1,646 

16,389 

693 

866 

221 

707 
34,967 

320 
1,151 
1.110 

171 

672 

1.951 

1.033 

3.174 

711 
480 
544 
467 
20.304 

305 
1,190 
1,300 

1,427 
402 

2,412 
1.075 
720 
9.476 
2,824 



$ 

127,645 

63,510 

47,454 

7,777 

344,766 

898.929 

238,416 

3,950 

31,998 

5.663 

46,933 

287,206 

17,725 

30,736 

5,549 

17,875 

1,256,417 

8,212 

29,193 

59,730 

6,795 
22,055 
72.935 
35.498 
96,925 

20.823 
13.236 
15.569 
85,389 
423.517 

8,072 
31,111 
20,040 
55.887 
11,704 

72,251 

43.408 

12,920 

205,636 

90,784 



kwh 

13.476,274 

4,967,684 

4,182,904 

497,737 

28,711,399 

79,600,305 
15,145,763 

343,755 
2,677,325 

391,950 

4,368,224 

28,252,255 

1,516,539 

2,263,191 

447,948 

1,263,363 

92,186.015 

426,351 

2,196,036 

6.731,536 

500.764 
1,853,940 
5,022.707 
3,251,724 
7,568,871 

1,443,275 

974,549 

1,399,294 

1,612,561 

23,652,169 

670,670 
2,746,780 
1,671,046 
3,944.488 

932,951 

5,859,962 
2,790,244 
1,768,748 
18,564.419 
6.952,187 



No. 


kwh 


2,270 


495 


909 


455 


734 


475 


154 


275 


4.998 


479 


15,140 


438 


2,037 


620 


85 


337 


431 


518 


183 


178 


900 


404 


5.124 


459 


294 


430 


384 


491 


78 


479 


310 


340 


12,792 


601 


194 


183 


649 


282 


1,188 


472 


81 


515 


371 


416 


854 


490 


629 


431 


1,577 


400 


359 


335 


324 


251 


2 70 


432 


837 


161 


8,050 


245 


143 


391 


590 


388 


365 


382 


942 


349 


205 


379 


1,101 


444 


648 


359 


371 


397 


3,077 


503 


1.074 


539 



For explanation of symbols see page 264. 



Statement D 



249 



Utilities and Local Systems 
AND CONSUMPTION 
December 31, 1960 



(inc 


Commercial service 
uding flat-rate water-heaters) 






Industria 


L POWER 


SERVICE 






Revenue 


Consumption 


Cus- 
tomers 


Monthly 
consumption 
per customer 


Av- 
erage 
cost 

per 
kwh 


Revenue 


Consumption 


Cus- 
tomers 


Average of cus- 
tomers'monthly 
loads billed 


Monthly 
consumption 
per customer 


Av- 
erage 
cost 
per 
kwh 


$ 


kwh 


No. 


kwh 


t 


$ 


kwh 


No. 


kw 


kwh 


i 


45.766 


3,917,448 


138 


2.366 


1.17 


78,626 


8,879,448 


38 


2,691 


19,472 


0.89 


46.756 


3,184,707 


204 


1,301 


1.47 


11,638 


628,858 


20 


465 


2,620 


1.85 


22.681 


1,430,082 


73 


1,633 


1.59 


24,852 


2,123,545 


29 


682 


6,102 


1.17 


1.198 


56,718 


5 


591 


2.11 


57,528 


5,183,634 


2 


1,640 


215,985 


1.11 


122.396 


7,513,555 


304 


2,060 


1.63 


154,690 


12,604,706 


90 


4,580 


11.671 


1.23 


373.591 


30,299,734 


1,570 


1.608 


1.23 


848,524 


91,453,761 


299 


30,558 


25,489 


0.93 


43.876 


2,425,709 


114 


1,773 


1.81 


98,611 


6,426,672 


44 


3,106 


12.172 


1.53 


2.665 


164,956 


13 


1.057 


1.62 


566 


22,896 


1 


26 


1,908 


2.47 


8.411 


573,962 


20 


2,392 


1.47 


3,599 


195,630 


9 


144 


1,811 


1.84 


4.736 


281,000 


24 


976 


1.69 


3,597 


135,045 


8 


150 


1,407 


2.66 


16.611 


1.087,556 


70 


1,295 


1.53 


7,087 


538,952 


11 


286 


4,083 


1.31 


126.973 


9.858.493 


662 


1,241 


1.29 


284,004 


34,217.917 


93 


9,659 


30,661 


0.83 


9.759 


545.400 


82 


554 


1.79 


7,455 


371,830 


9 


185 


3,443 


2.00 


9.367 


474.289 


37 


1,068 


1.97 


5.107 


273,660 


6 


158 


3.801 


1.87 


2.115 


98,503 


19 


432 


2.15 


2,759 


55.210 


3 


97 


1,534 


5.00 


8.009 


474.180 


27 


1,464 


1.69 


5,979 


409,780 


4 


155 


8,537 


1.46 


297,270 


17,605,949 


613 


2,393 


1.69 


357,986 


27,481.337 


142 


9,499 


16.128 


1.30 


501 


21.580 


4 


450 


2.32 


18,291 


900,264 


3 


403 


25.007 


2.03 


19.812 


1.271,113 


115 


921 


1.56 


11,092 


784,282 


24 


322 


2,723 


1.41 


25.017 


2.247.014 


129 


1.452 


1.11 


11,755 


1.233,699 


29 


496 


3.545 


0.95 


1.142 


74.280 


8 


774 


1.54 


632 


63,400 


1 


10 


5.283 


1.00 


8.322 


426,867 


67 


531 


1.95 


5,594 


303,013 


12 


166 


2.104 


1.85 


15.963 


983,122 


96 


853 


1.62 


12,160 


992,241 


3 


281 


27,562 


1.23 


6.313 


413,160 


29 


1,187 


1.53 


1,262 


108,440 


5 


37 


1,807 


1.16 


26.129 


1,437,271 


107 


1,119 


1.82 


43,019 


4,072,039 


28 


1,269 


12,119 


1.06 


4.369 


224,036 


14 


1,334 


1.95 


11,641 


694,155 


6 


335 


9.641 


1.68 


8.020 


481,862 


38 


1,057 


1.66 


4,470 


137,360 


9 


198 


1.272 


3.25 


4.066 


330,818 


18 


1,532 


1.23 


2,853 


262,630 


2 


95 


10.943 


1.09 


37.294 


608,311 


104 


487 


6.13 


13,650 


395,374 


18 


171 


1.830 


3.45 


432.165 


20,812,443 


1,204 


1,441 


2.08 


524,899 


41,930,632 


255 


14,568 


13.703 


1.25 


4.046 


237,230 


21 


941 


1.71 


848 


34,125 


1 


26 


2,844 


2.48 


14,544 


794.700 


102 


649 


1.83 


11,086 


675,099 


25 


419 


2,250 


1.64 


10,538 


607,619 


81 


625 


1.73 


34,241 


3,367,647 


11 


919 


25.512 


1.02 


16,738 


835.533 


82 


849 


2.00 


3,990 


405,950 


11 


125 


3.075 


0.98 


3,275 


200.171 


15 


1,112 


1.64 


4,219 


341,850 


7 


104 


4.070 


1.23 


29,342 


1,761.696 


102 


1.439 


1.67 


21,888 


1,577.315 


29 


649 


4.533 


1.39 


21,854 


999,978 


118 


721 


2.19 


9.034 


803.923 


5 


210 


8,932 


1.12 


3,667 


297,480 


24 


1,033 


1.23 


3.301 


210.003 


8 


193 


2.188 


1.57 


75,342 


5,089.017 


241 


1,760 


1.48 


174.402 


18,071,824 


69 


5,135 


21.826 


0.97 


55,479 


2,956,477 


198 


1.244 


1.88 


20.201 


1,773.629 


27 


535 


5.474 


1.14 



250 



Municipal Electrical Service 



Municipal Electrical 

CUSTOMERS, REVENUE, 

for the Year Ended 



Municipality 



Popula- 
tion 



Total 
customers 



Peak 
load 
Decem- 
ber 
1960 



Residential service 
(including flat-rate water-heaters) 



Revenue 



Consumption 



Cus- 
tomers 



11 

>. a 2 

2 E » 
c g « 
o c ^ 
S 8 a 



Col borne. . . 
^>Coldwater. . 
#>Collingwood . 

#Comber 

#Coniston. . . 



#Cookstown . 
#Cottam. . . . 
<$>Courtright . 
Creemore. . 
<#Dashwood . 



#Deep River. 
Delaware . . . 

♦ Delhi 

#Deseronto. . 

# Dorchester. 



#Drayton. 
"^Dresden. 
#Drumbo. 
#Dryden . 
^Dublin. . 



#Dundalk. . 

Dundas. . 

Dunnville. 

Durham. . 
«>Dutton. . . 



«>East York Twp. . . . 

Eganville 

#tEIk Lake Townsite. 

#Elmira 

#Elmvale 



4> Elm wood. 

Elora. . . . 

Embro. . . 

#fEngIehart 

*>Erieau . . . . 



#Erie Beach 

#Erin 

#JEspanola 

#Essex 

#Etobicoke Twp. (including 
Thistletown) 



No. 
1,337 

752 
8.505 

580 
2,569 

650 
649 

548 
882 
433 

5,130 

452 

3,434 

1,770 

937 

620 
2,311 

399 
5,740 

271 

875 

12,790 

5,261 

2,084 

777 

68,209 

1,454 

§600 

3,222 

942 

§450 

1,509 

547 

1,689 

477 

*130 
1,010 
5,068 
3,416 

144,777 



fo. 


kw 


572 


963 


270 


571 


3,115 


6.520 


234 


274 


668 


1.190 


250 


383 


244 


282 


191 


188 


363 


555 


183 


288 


1,383 


3,996 


136 


255 


1,364 


3,018 


638 


911 


327 


508 


263 


424 


895 


1,524 


174 


252 


1.691 


3,127 


111 


266 


426 


696 


4.010 


9,161 


1,913 


3,491 


822 


1,489 


343 


470 


22,769 


40,491 


567 


626 


208 


480 


1,143 


3,980 


406 


652 


138 


259 


530 


881 


232 


432 


611 


1,053 


350 


327 


139 


59 


405 


683 


1,289 


2,684 


1,205 


1,714 


49,238 


127.505 



$ 

28,706 

13,869 

143,060 

7,865 

49,135 

11,947 
8,925 
5,712 
16,553 
11,495 

129,230 
10,665 
57,586 
28.806 
14,962 

14,253 

30,907 

9,464 

127.171 

5,415 

17,813 
224,536 
65,460 
38,897 
11,775 

1,217,245 
27,146 
10,060 
71,882 
20,326 

4,695 
33,675 
13,283 
38,961 
12,209 

4,391 
22,141 
31,907 
48,010 

3,669,098 



kwh 


No. 


2,392,742 


472 


1.227,359 


250 


12,573,122 


2,878 


488,380 


201 


3,721,920 


651 


959,096 


229 


655,440 


221 


447,224 


178 


1,446,040 


301 


732,941 


173 


10,600,245 


1,290 


742,008 


118 


5,064,061 


1,190 


2,597,590 


594 


1,172.165 


310 


946.230 


238 


1,942,696 


807 


795,570 


160 


10,249,714 


1,548 


469,387 


96 


1,323,310 


376 


19,102,174 


3,532 


3,997,999 


1,589 


3,211,930 


675 


837,828 


314 


117,481,857 


21,802 


1,726,509 


464 


682,616 


154 


6,082,704 


1,043 


1,804,217 


365 


374,570 


127 


2,238.759 


452 


1,089.186 


186 


2,416,528 


510 


929,497 


292 


146,840 


133 


1,741,958 


368 


2,121,852 


1,204 


3,361.680 


1,072 


311.309.537 


46,495 



kwh 
422 
432 
382 
202 
476 

365 
247 
209 
400 
353 

685 
524 
355 
364 
315 

331 
201 
414 
552 
407 

293 
451 
210 
397 

222 

449 
310 
369 
486 
412 

246 
413 
488 
395 
265 

92 
394 
587 
261 

558 



JThree months' operation. 
For explanation of symbols 9ee page 264. 



Statement D 



251 



Utilities and Local Systems 
AND CONSUMPTION 
December 31, 1960 



Commercial service 
(including flat-rate water-heaters) 




Industrial power 


SERVICE 












c jrj 


Av- 








35 


c fc 


Av- 








•2 § 


erage 








•B §"S 


■2 i 


erage 


Revenue 


Consumption 


Cus- 
tomers 


Monthly 
consumpi 
per custo 


cost 
per 
kwh 


Revenue 


Consumption 


Cus- 
tomers 


Average 
tomers'm 
loads bill 


Monthly 
consumpi 
per custo 


cost 
per 
kwh 


$ 


kwh 


No. 


kwh 


i 


$ 


kwh 


No. 


kw 


kwh 


i 


14,330 


679,858 


91 


623 


2.11 


4.994 


346,042 


9 


134 


3,204 


1.44 


4,559 


265.533 


16 


763 


1.72 


10,342 


837,444 


4 


302 


17,447 


1.23 


73,886 


4,873,660 


173 


1,310 


1.52 


90.945 


8,517.771 


64 


3,645 


11,091 


1.07 


5,022 


259,950 


25 


867 


1.93 


6,312 


245,720 


8 


231 


2,560 


2.57 


5,929 


299,835 


15 


1.666 


1.98 


788 


64,060 


2 


19 


2,669 


1.23 


2,941 


109,534 


17 


338 


2.68 


2,483 


156,100 


4 


89 


3,252 


1.59 


2,885 


141,485 


16 


737 


2.04 


3,706 


90,754 


7 


191 


1,080 


4.08 


1,402 


98,099 


11 


743 


1.43 


684 


75,202 


2 


18 


3,133 


0.91 


5,898 


311,320 


56 


463 


1.89 


2,452 


111,650 


6 


110 


1,551 


2.20 


1,294 


63,270 


6 


879 


2.05 


3.441 


120,530 


4 


124 


2,511 


2.86 


52,898 


3,460,696 


85 


3.393 


1.53 


7.725 


739,902 


8 


183 


7,707 


1.04 


3,414 


140,322 


18 


650 


2.43 














41,610 


2,586,427 


132 


1,633 


1.61 


37,601 


2,306,429 


42 


1,354 


4.576 


1.63 


5,956 


398,007 


27 


1,228 


1.50 


14,913 


1.021,290 


17 


592 


5,006 


1.46 


2,047 


107,964 


14 


643 


1.90 


2,289 


109,857 


3 


81 


3,052 


2.08 


3,309 


156,725 


21 


622 


2.11 


3,625 


129,202 


4 


126 


2,692 


2.81 


23,534 


1,511,397 


63 


1,999 


1.56 


41,378 


2,283,445 


25 


1,235 


7,611 


1.81 


1,284 


65,770 


11 


498 


1.95 


1,558 


42,034 


3 


69 


1,168 


3.71 


59,380 


3,546,935 


122 


2,423 


1.67 


7,126 


404,340 


21 


233 


1,605 


1.76 


2,669 


1 73,900 


13 


1,115 


1.53 


3,108 


121,600 


2 


77 


5,067 


2.56 


8,098 


384,533 


38 


843 


2.11 


5,407 


256,453 


12 


218 


1,781 


2.11 


118,975 


7,374,358 


395 


1,556 


1.61 


96,702 


8,670,830 


83 


3,393 


8,706 


1.12 


64,819 


3,441,548 


286 


1,003 


1.88 


89,604 


7,059,710 


38 


2,388 


15,482 


1.27 


19,050 


1,003,038 


122 


685 


1.90 


30,102 


1,598,445 


25 


955 


5,328 


1.88 


3,480 


191,690 


16 


998 


1.82 


6,583 


429,870 


13 


236 


2,756 


1.53 


291,546 


22,889,541 


878 


2,329 


1.27 


297,101 


31,812,739 


89 


9,788 


17,913 


0.93 


20,842 


904,501 


91 


828 


2.30 


6,985 


452.545 


12 


186 


3,143 


1.54 


6,298 


413,641 


52 


683 


1.52 


7,957 


209,689 


2 


230 


4,993 


3.79 


28,078 


1,682,061 


69 


2.031 


1.67 


86,814 


7,998,594 


31 


2,332 


21,502 


1.09 


6,870 


440,429 


33 


1,112 


1.56 


1,959 


176,983 


8 


54 


1,844 


1.11 


1,153 


76,890 


9 


712 


1.50 


1,404 


48,440 


2 


60 


2,018 


2.90 


11,013 


477.709 


72 


553 


2.31 


6,943 


445,960 


6 


196 


6,194 


1.56 


3,591 


247,659 


42 


491 


1.45 


4,412 


181,343 


4 


109 


3,778 


2.43 


17.346 


720,378 


97 


629 


2.41 


6,711 


525,284 


4 


140 


7,959 


1.28 


6,606 


425.650 


52 


682 


1.55 


7,921 


344.360 


6 


266 


4,783 


2.30 


363 


12,350 


6 


172 


2.94 














6,529 


380,102 


32 


990 


1.72 


2,152 


123.910 


5 


72 


2,065 


1.74 


10,506 


608,960 


83 


2.417 


1.73 


93 


2,080 


2 


22 


347 


4.46 


33,222 


2,125,961 


103 


1,720 


1.56 


18,314 


925,091 


30 


714 


2,570 


1.98 


1,003,966 


70,056,709 


1.876 


3,112 


1.43 


1,825.605 


196,591,035 


867 


54,944 


18,896 


0.93 



252 



Municipal Electrical Service 



Municipal Electrical 

CUSTOMERS, REVENUE, 

for the Year Ended 



Municipality 



Popula- 
tion 



Total 
customers 



Peak 
load 
Decem- 
ber 
1960 



Residential service 
(including flat-rate water-heaters) 



Revenue 



Consumption 





>» a 2 


Cus- 


2 E § 


tomers 


C 5 u 

O C i- 




s s & 



Exeter 

Fergus 

<#Finch 

^Flesherton 

Fonthill 

#>Forest 

#>Forest Hill 

Fort William .... 
<#Frankford 

Gait 

#Georgetown 

#>fGeraldton 

<#Glencoe 

#Goderich 

<^fGogama 

Grand Bend 

Grand Valley. . . . 

Granton 

<f>Gravenhurst 

Grimsby 

<#Guelph 

Hagersville 

MHaileybury 

Hamilton 

Hanover 

#Harriston 

#Harrow 

#Hastings 

#Havelock 

#Hawkesbury 

#Hearst 

Hensall 

•#tHepworth 

Hespeler 

Highgate 

Holstein 

fHornepayne 

4>|Hudson Townsite 

Huntsville 

Ingersoll 



No. 

2,977 

3,894 

403 

495 

2,321 

2,065 
20,225 
43,968 

1,576 
26,945 

10,015 

3,479 

1,144 

6,232 

§500 

*906 

641 

303 

3,133 

4,804 

38,323 

2,087 

2.607 

261,114 

4,348 

1,628 
1,842 
899 
1,271 
8,730 

2,102 
903 
388 

4,461 
382 

177 

§1,400 

§600 

3,200 

7,174 



No. 

1,208 

1.336 

176 

251 

777 

892 

7,678 

13.719 

574 
8.947 

3.244 
1,069 

492 
2,345 

133 

828 

316 

119 

1,331 

1,737 

12,103 

771 

886 

80.211 

1,602 

659 
674 

452 

458 

2,185 

719 
366 
127 
1,423 
165 

96 

479 

223 

1.215 

2,353 



kw 

2,408 

3,677 
286 
460 

1,434 

1,474 

15,528 

36,850 

811 

25,020 

8,523 
1.459 

649 
6,073 

240 

680 

498 

121 

2,533 

2.986 

35,648 

1,678 

1,701 

327,459 

4,062 

1,274 

1,375 

470 

627 

3.386 

1.274 
763 
160 

5.495 
218 

127 

656 

495 

2,478 

5,669 



$ 

73,475 

91,922 
7,409 
8,588 

49,141 

46,835 
536,938 
747,584 

28,249 
509,841 

205,639 
67,604 
13,769 

136,459 
10,368 

38,007 
14,001 
6,270 
54,577 
73,889 

797,344 

27,572 

59,258 

4,083,296 

78,815 

34,900 
42,041 
15,439 
21,783 
127,561 

52,797 
18,632 

6,576 
73,348 

4.078 

3,516 
42,902 

9,179 
63,648 
117.391 



kwh 

5.544.794 

6,773.080 
691,932 
920.144 

3,878,758 

4,297,671 
52,599,080 
96,082,799 

2,520,942 
42,830,590 

17,231,205 
4,077,817 
1.113,841 

11,125,061 
340,445 

1,874,790 
1,023,080 
376,610 
5,993,490 
6,444,584 

68,484,628 

2,088,951 

4,219,045 

354,023,802 

7,490,855 

2,825,640 
3,515,081 
1,364,605 
1,639,803 
9,091,391 

2,791,262 
1,609,312 

406,358 
5,716,185 

285,826 

282.760 
1,620,236 

434,961 
5,611,180 
7,884,759 



No. 


kwh 


997 


463 


1,163 


485 


162 


356 


224 


342 


697 


464 


824 


435 


7,256 


604 


11,976 


669 


542 


388 


7,914 


451 


3,025 


475 


880 


386 


427 


217 


2,149 


431 


112 


253 


709 


220 


251 


340 


98 


320 


1,197 


417 


1,467 


366 


10,946 


521 


594 


293 


715 


492 


70,371 


419 


1,368 


456 


597 


394 


585 


501 


428 


266 


428 


319 


2,056 


368 


638 


365 


285 


471 


112 


302 


1,261 


378 


125 


191 


77 


306 


427 


316 


185 


196 


975 


480 


2,038 


322 



For explanation of symbols see page 264. 



Statement D 



253 



Utilities and Local Systems 
AND CONSUMPTION 
December 31, 1960 



(incl 


Commercial service 
uding flat-rate water-heaters) 






Industrial power 


SERVICE 












c !a 


Av- 








an Ji > 

35 


e fe 


Av- 






Cus- 


hly 

mptio 

jstomi 


erage 
cost 






Cus- 


ige of 
-s'mor 
billed 


hly 

mptio 

istom< 


erage 
cost 


Revenue 


Consumption 


tomers 


Mont 
consu 
per ci 


per 
kwh 


Revenue 


Consumption 


tomers 


Aven 
tomei 
loads 


Mont 
consu 
per a 


per 
kwh 


$ 


kvvh 


No. 


kwh 


i 


$ 


kwh 


No. 


kw 


kwh 


i 


31,536 


1,763,737 


178 


826 


1.79 


23,311 


1,224,520 


33 


788 


3,092 


1.90 


32,317 


1,612,016 


143 


939 


2.00 


65.972 


4,991,870 


30 


1,909 


13,866 


1.32 


1,386 


73,212 


9 


678 


1.89 


2.770 


123,460 


5 


124 


2,058 


2.24 


4,521 


324,216 


25 


1,081 


1.39 


1.585 


107,380 


2 


68 


4,474 


1.48 


12,824 


736,238 


69 


889 


1.74 


4.061 


192,330 


11 


121 


1,457 


2.11 


15,914 


1,008,744 


45 


1,868 


1.58 


11.636 


992,542 


23 


399 


3,596 


1.17 


151,304 


12,011,830 


393 


2,547 


1.26 


10,239 


1,116,900 


29 


350 


3.209 


0.92 


370,160 


36,883,798 


1.522 


2,019 


1.00 


492,246 


58,052,450 


221 


20,525 


21,890 


0.85 


4,344 


283,652 


27 


875 


1.53 


1,873 


141,764 


5 


86 


2,363 


1.32 


189,897 


10,958.086 


819 


1,115 


1.73 


511,202 


52,098,108 


214 


17.032 


20,287 


0.98 


60,680 


3.870,573 


178 


1.812 


1.57 


127,390 


13,715,549 


41 


3,469 


27,877 


0.93 


38,667 


1,951,818 


173 


940 


1.98 


1,961 


61,849 


16 


72 


322 


3.17 


13,561 


869,695 


48 


1.510 


1.56 


8.162 


312,393 


17 


364 


1,531 


2.61 


45,414 


2,431.167 


141 


1,437 


1.87 


150,462 


11,211,832 


55 


4.040 


16,988 


1.34 


4,293 


182,444 


19 


800 


2.35 


4,301 


226,810 


2 


57 


9,450 


1.90 


25,860 


1,123,100 
296,880 


119 

57 


786 
434 


2.30 
2.16 














6,406 


4,224 


210,720 


8 


146 


2.195 


2.00 


1,433 


51,340 


20 


214 


2.79 


177 


1,700 


1 


8 


142 


10.40 


26,926 


2,369,913 


105 


1,881 


1.14 


27,596 


2,657,975 


29 


1.117 


7.638 


1.04 


47,981 


3,112,339 


235 


1,104 


1.54 


28.893 


2,405,216 


35 


946 


5.727 


1.20 


317,340 


22,250,038 


1.009 


1,838 


1.43 


682,845 


75,203,631 


148 


20,342 


42,344 


0.91 


27,341 


1,616,753 


151 


892 


1.69 


38,970 


2,575,493 


26 


1,426 


8,255 


1.51 


34,385 


1,676,950 


162 


896 


2.05 


8,483 


624,548 


9 


252 


3,470 


1.36 


2,232,234 


180,089,452 


8,439 


1.778 


1.24 


9,085,031 


1,358.254,659 


1.401 


265,679 


80,791 


0.67 


29,206 


1,919.725 


195 


820 


1.52 


58,208 


5,218,923 


39 


2,178 


11.152 


1.12 


11,587 


669,870 


49 


1,139 


1.73 


22,413 


1,969,131 


13 


621 


12.623 


1.14 


21,840 


1,298.063 


77 


1,405 


1.68 


16,459 


734.550 


12 


567 


5,101 


2.24 


2,604 


197,940 


19 


868 


1.32 


2,592 


194.084 


5 


110 


3,235 


1.34 


7,018 


462,371 


27 


1.427 


1.52 


1,732 


140,500 


3 


62 


3,903 


1.23 


60,684 


3,413,690 


104 


2,735 


1.78 


13,463 


922,315 


25 


545 


3,074 


1.46 


26,938 


1,307,869 


70 


1,557 


2.06 


3,881 


225.885 


11 


78 


1.711 


1.72 


9,570 


537,309 


60 


746 


1.78 


14,752 


771,650 


21 


486 


3,062 


1.91 


2.595 


126,883 


15 


705 


2.05 














23,413 


1,297,378 


128 


845 


1.80 


146.051 


17,084.750 


34 


4.352 


41.874 


0.85 


3,138 


151,210 


36 


350 


2.08 


4,440 


158,090 


4 


136 


3.294 


2.81 


993 


47,630 


17 


233 


2.08 


909 


67,800 


2 


18 


2,825 


1.34 


22,510 


623.017 


51 


1,018 


3.61 


8,177 


708,000 


1 


110 


59.000 


1.15 


5,172 


266,724 


34 


654 


1.94 


9,811 


308,151 


4 


225 


6,420 


3.18 


53,429 


3,371,194 


206 


1.364 


1.58 


27,126 


2,606,019 


34 


926 


6.387 


1.04 


58.175 


3,341.386 


269 


1.035 


1.74 


131,229 


12,099,532 


46 


4,027 


21,919 


1.08 



254 



Municipal Electrical Service 

Municipal Electrical 

CUSTOMERS, REVENUE, 

for the Year Ended 



Municipality 



Popula- 
tion 



Total 
customers 



Peak 
load 
Decem- 
ber 
1960 



Residential service 
(including flat-rate water-heaters) 



Revenue 



Consumption 



Cus- 
tomers 


Monthly 
consumption 
per customer 


No. 


kwh 


327 


521 


260 


232 


42 


244 


1,810 


472 


181 


420 


693 


419 


1,088 


384 


161 


434 


13,208 


587 


1,098 


312 


95 


260 


5,018 


403 


21,244 


518 


610 


477 


555 


465 


265 


285 


191 


339 


511 


481 


142 


173 


2,982 


298 


3,466 


436 


1,385 


420 


29.693 


342 


971 


478 


4,056 


404 


338 


263 


330 


438 


360 


342 


160 


477 


522 


384 


104 


210 


348 


391 


1,227 


561 


439 


371 


110 


286 


316 


425 


254 


280 


237 


549 


684 


335 


281 


324 



Iroquois 

#Jarvis 

^fjellicoe Townsite 

-$>Kapuskasing 

^fKearns Townsite 

#Kemptville 

^Kincardine 

#fKing Kirkland Townsite. 
Kingston 

# Kings ville 

#Kirkneld 

^>tKirkland Lake (including 

Swastika) 

Kitchener 

Lakefield 

Lambeth 

# Lanark 

<§> Lancaster 

Larder Lake Twp 

<#>Latchford 

<§> Leamington 

^Lindsay 

#Listowel 

London 

^•London Twp 

3>Long Branch 

#L'Orignal 

<§>Lucan 

Lucknow 

#Lynden 

#Madoc 

#Magnetawan 

Markdale 

#>Markham 

Marmora 

#Martintown 

#Massey 

#fMatachewan Twp 

#tMatheson 

<@>fMattawa 

#Maxville 



No. 

1,014 

755 

§140 

6,444 

§500 

1,914 
2,691 
§500 
48,028 
3,089 

134 

§18,495 

72,961 

2,073 

1,926 

875 
612 

1,990 
437 

8,602 

11,052 

3,665 

119,616 

43,953 

10,783 

1,145 
945 

1,009 
530 

1,488 

256 
1,113 
4,319 
1,358 

430 

1,325 
912 
910 

3.151 
813 



No. 

395 

285 

52 

2,015 

194 

764 
1,205 

183 

15,497 

1,249 

102 

5,956 

23,324 

729 

604 

281 
208 
561 
155 
3.280 

3,754 

1,528 

33,107 

997 

4,243 

358 
355 
471 
167 
596 

107 
440 
1,334 
522 
125 

356 
296 
307 
811 
313 



kw 
879 
444 
66 

4,101 
346 

1,727 

2,126 

280 

42,523 

2,334 

92 

10,284 

68,996 

1,438 

1,121 

335 
337 
999 
139 
6,149 

8,926 
3,363 
71,320 
2,139 
7.690 

427 
670 
730 
342 
974 

96 

792 

3,262 

918 

177 

546 

272 

612 

1,385 

478 



$ 

25,722 

10,027 

2,441 

119,065 
12,347 

36,718 

52,118 

11,582 

851,280 

45,098 

4,616 

351,398 

1,513,662 

35,289 

43,159 

9,527 

8,548 

37,763 

4,823 

138,494 

198,169 

79,889 

1,501,625 

72,657 

226,542 

17,770 
22,718 
16,899 
10,733 
24,424 

5,481 

18,001 

102,016 

25,009 

4,995 

30,102 
12,850 
19,860 
54,281 
12,899 



kwh 

2,045.073 

684.764 

122.777 

10,250.980 

911,395 

3,485,870 

5,015,143 

838,659 

93,027,078 

4,117,221 

296,030 

24,260,902 

132,063,086 

3,490,582 

3,099,410 

907,417 

776,137 

2,952,240 

294,790 

10.656,075 

18,152,730 

6,974,852 

121,856,121 

5,564,924 

19,678.224 

1.065,520 
1,736,054 
1,477,550 
916,335 
2,408,071 

262,690 
1,634,216 
8,261,538 
1,954,356 

377,310 

1,613,052 
852,141 
1,560,194 
2.747,028 
1,091,569 



For explanation of symbols see page 264. 



Statement D 



255 



Utilities and Local Systems 
AND CONSUMPTION 
December 31, 1960 



Commercial service 
(including flat-rate water-heaters) 




Industrial power 


SERVICE 












a !b 


Av- 










c !r, 


Av- 


Revenue 


Consumption 


Cus- 
tomers 


Monthly 
consumptio 
per custom* 


erage 
cost 
per 
kwh 


Revenue 


Consumption 


Cus- 
tomers 


Average of 
tomers'mon 
loads billed 


Monthly 
consumptio 
per custom* 


erage 
cost 
per 
kwh 


$ 


kwh 


No. 


kwh 


i 


$ 


kwh 


No. 


kw 


kwh 


i 


14,733 


850.200 


61 


1,161 


1.73 


4.971 


365,170 


7 


153 


4,347 


1.36 


5,088 


287,326 


17 


772 


1.77 


6,089 


405,500 


8 


180 


4,224 


1.50 


1,866 


115.206 


9 


1,067 


1.62 


479 


15,800 


1 


14 


1,317 


3.03 


67.926 


4,175.659 


173 


2.011 


1.63 


8,287 


458,054 


32 


336 


1.193 


1.81 


2,684 


140,938 


12 


979 


1.90 


608 


29,070 


1 


15 


2,423 


2.09 


18,051 


1,274.605 


60 


1.770 


1.42 


23,202 


1,704,821 


11 


778 


12,915 


1.36 


22,590 


1,399,649 


94 


1.241 


1.61 


41,060 


3,204,602 


23 


1,197 


11.611 


1.28 


3,826 


218.125 
61,163,191 


22 
2,055 


826 
2,480 


1.75 
1.16 














706.999 


402,304 


43,315,397 


234 


13,728 


15,426 


0.93 


27,462 


1,744.252 


118 


1,232 


1.57 


23,834 


1,463,095 


33 


1.067 


3.695 


1.63 


752 


27,131 
11,615,670 


7 
907 


323 
1,118 


2.77 
1.48 














172.248 


56,887 


4,361,288 


31 


1.738 


5,013 


1.30 


698.580 


44,720.135 


1,714 


2,174 


1.56 


1,419,088 


138,210,898 


366 


39,968 


31.469 


1.03 


19,488 


1,243,418 


103 


1,006 


1.57 


7,153 


407,351 


16 


317 


2.122 


1.76 


6,944 


290,753 


48 


505 


2.39 


1,469 


70,895 


1 


30 


5,908 


2.07 


2,066 


148,498 


14 


884 


1.39 


2,619 


201,980 


2 


94 


8.416 


1.30 


4,240 


321.993 
606,930 


17 
47 


1,578 
1,076 


1.32 
1.80 














10.945 


1,646 


178,967 


3 


30 


4.971 


0.92 


2.093 


143,663 


10 


1,197 


1.46 


3,021 


200,490 


3 


92 


5.569 


1.51 


74,202 


4,745,640 


216 


1,831 


156 


134,259 


12,410,405 


82 


3,621 


12,612 


1.08 


79,434 


5,264,503 


199 


2,205 


1.51 


168,107 


17,870,328 


89 


5,241 


16.733 


0.94 


35.629 


2,259,680 


109 


1,728 


1.58 


40,454 


2,859.676 


34 


1.286 


7,009 


1.41 


1.044,007 


78,046,850 


2,983 


2,180 


1.34 


1.322,275 


155.845,821 


431 


43.222 


30.133 


0.85 


7.629 


487,847 


19 


2,140 


156 


11,607 


1,171,589 


7 


291 


13.947 


0.99 


58.508 


4,033,925 


142 


2,367 


1.45 


83.865 


7.532,446 


45 


2.718 


13.949 


1.11 


5.155 


332.089 


17 


1,628 


1.55 


1,205 


36.235 


3 


60 


1,007 


3.33 


5,539 


317,783 


19 


1,394 


1.74 


2,972 


178.155 


6 


97 


2,474 


1.67 


10.112 


603,430 


99 


508 


1.68 


12,767 


660.950 


12 


344 


4.590 


1.93 


2.285 


135,000 


5 


2,250 


1.69 


1,939 


55,575 


2 


92 


2.316 


3.49 


14.007 


997,293 


62 


1,340 


1.40 


4,597 


230,751 


12 


183 


1,602 


1.99 


939 


35.250 
821,640 


3 

85 


979 
806 


2.66 
1.61 














13,204 


2,482 


149,455 


7 


88 


1,779 


1.66 


43,412 


2.827,079 


89 


2,647 


1.54 


18,047 


914,373 


18 


635 


4,233 


1.97 


16,235 


856,473 


78 


915 


1.90 


2,720 


190.360 


5 


75 


3.173 


1.43 


2,094 


122.895 


14 


732 


1.70 


522 


15.150 


1 


33 


1.263 




9.338 


490.300 


40 


1,078 


1.90 


830 


45.848 




18 




1.81 


5,309 


281.576 
525.511 


42 
67 


559 
654 


1.89 
1.71 














9.001 


2.347 


147.051 


3 


55 


4.085 


1.60 


33,792 


1,440.560 


124 


984 


2.35 


20,031 


947,570 


3 


411 


15,793 


2.11 


5.904 


334.180 


28 


995 


1.77 


3,530 


127,400 


4 


131 


2.654 


2.77 



256 



Municipal Electrical Service 



Municipal Electrical 

CUSTOMERS, REVENUE, 

for the Year Ended 



Municipality 



Popula- 
tion 





Peak 




load 




Decem- 


Total 


ber 


customers 


1960 



Residential service 
(including flat-rate water-heaters) 



Revenue 



Consumption 





y 

ption 
.omer 


Cus- 


onthl 
nsum 
r cus 


tomers 




5 o }; 
« y a 



Av- 
erage 
cost 
per 



McGarry 

Meaf ord 

Merlin 

#Merrickville 

Merritton 

^Midland 

Mildmay 

#Millbrook 

^>Milton 

#>Milverton 

^>Mimico 

«>Mitchell 

#Moorefield 

#Morrisburg 

3>Mount Brydges 

#>Mount Forest 

#Napanee 

#Neustadt 

#Newboro 

Newburgh 

Newbury 

Newcastle 

#New Hamburg 

#tNew Liskeard 

Newmarket 

#>New Toronto 

Niagara 

#Niagara Falls 

^Nipigon Twp 

North Bay 

North York Twp. . . . 

Norwich 

^Norwood 

Oakville- ^Trafalgar 
<|>Oil Springs 

Omemee 

#Orangeville 

Orillia 

^Orono 

#Oshawa 



No. 

2,944 

3,672 

612 

891 

6,497 

8,615 

836 

842 

5,394 

1,075 

16,380 

2,161 

303 

1,912 

957 

2,571 

4,505 

505 

291 

573 

343 
1,198 
2,100 
4,700 
8,055 

11,664 
2,669 

22,575 
2,700 

23,010 

244,145 

1,705 

1,110 

40,540 

480 

813 
4,643 
14,515 

897 
60,135 



No. 

480 

1,510 
255 
355 

2,001 

2,851 
305 
338 

1,720 
473 

6,641 
912 
124 
744 

355 

1,018 

1,686 

205 

145 

192 

130 

469 

711 

1,615 

2,726 

4,052 
1,068 
7,480 
731 
7.499 

79,727 
673 
412 

10,840 
225 

302 

1,694 

5,421 

364 

19,255 



kw 

1,039 

2,970 

334 

482 

18,883 

8.496 
681 
508 

4,441 
883 

9.873 
2,175 

256 
1.478 

374 

2.161 

3,509 

291 

108 

253 

124 

923 

1,384 

3,375 

7,062 

26.148 
1,822 

17,315 
1,699 

16,879 

189,151 

1,018 

640 

34,623 

301 

449 

3,620 

7,466 

520 

67,591 



$ 

37,425 

68,364 

7,332 

15,957 

109,170 

128,905 
13,829 
18,662 

118,310 
26,444 

293,942 

51,786 

5,273 

37,163 

15,256 

52,052 

87,593 

6,613 

5,084 

10,596 

4,905 

20,358 

41,348 

118,927 

156,394 

225,068 
67,660 

380,168 
36,728 

461,843 

5,215,014 

36,824 

19,187 

818,540 

6,547 

13,979 
108,782 
259,412 

18,826 
979,496 



kwh 


No. 


3.047,231 


429 


6,147.493 


1,276 


534.924 


186 


1,274.371 


328 


8,777.283 


1,787 


15,432,605 


2,644 


1,287,205 


236 


1,498,478 


321 


9,719,157 


1,567 


1,755,245 


409 


30,259,929 


6.347 


3,929,165 


821 


458,551 


109 


3,795,866 


657 


891,852 


331 


4,650,480 


914 


8,428,890 


1,505 


680,310 


187 


287,053 


134 


687.589 


163 


313,035 


106 


1,855,320 


389 


3,536,215 


644 


8,348,525 


1,430 


14,670,100 


2,347 


20,610,208 


3,746 


5.738.450 


928 


30,130,765 


6,889 


4,025,990 


666 


39,938,924 


6,273 


479,034,282 


72,372 


2,839,798 


557 


1,711,479 


373 


66,450,004 


9,851 


449,713 


178 


1,123,124 


257 


8,912,550 


1,530 


26,650,044 


4,620 


1,490,081 


342 


116.597,560 


17.359 



kwh 
592 
401 
240 
324 
409 

486 
455 
389 
517 
358 

397 
399 
351 
481 
225 

424 
467 
303 
179 
352 

246 
397 

458 
487 
521 

458 
515 
364 
504 
531 

552 
425 
382 
562 
211 

364 
485 
481 
363 
560 



For explanation of symbols see page 264. 



Statement D 



257 



Utilities and Local Systems 
AND CONSUMPTION 
December 31, 1960 



Commercial service 
(including flat-rate water-heaters) 




Industrial power 


service 












c h 


Av- 








S3 


c Si 


Av- 






Cus- 


hly 

mptio 

jstom< 


erage 
cost 






Cus- 


ige of 
's'mon 
billed 


hly 
mptio 

jstorm 


erage 
cost 


Revenue 


Consumption 


tomers 


Mont 
consu 
per ci 


per 
kwh 


Revenue 


Consumption 


tomers 


Aven 

tomei 
loads 


Mont 
consu 
per ci 


per 
kwh 


$ 


kwh 


No. 


kwh 


i 


$ 


kwh 


No. 


kw 


kwh 


i 


15,142 


841,124 


48 


1,460 


1.80 


1,232 


82,890 


3 


26 


2,303 


1.49 


31,461 


2,100,230 


199 


879 


1.50 


41,485 


3,258,509 


35 


1,203 


7,758 


1.27 


8,255 


483,980 


65 


620 


1.71 


2.777 


97,251 


4 


83 


2.026 


2.86 


2,751 


174,880 


20 


729 


1.57 


3,894 


336,060 


7 


152 


4,001 


1.16 


72,680 


4,052,393 


191 


1,768 


1.79 


651,627 


92,303,009 


23 


16,570 


334.431 


0.71 


47,992 


4,180,302 


144 


2,419 


1.15 


129,063 


15,063,532 


63 


6.163 


19,925 


0.86 


6,453 


365,423 


61 


499 


1.77 


4,459 


276,244 


8 


143 


2,878 


1.61 


3.798 


179,525 


14 


1,069 


2.12 


745 


43,107 


3 


19 


1,197 


1.73 


39,212 


2,446.317 


133 


1,618 


1.60 


74,885 


5,727,660 


20 


2,010 


17,678 


1.31 


11,768 


568,878 


48 


988 


2.07 


12,861 


656,151 


16 


431 


3,417 


1.96 


100,408 


7,524,812 


252 


2,488 


1.33 


59,020 


4,790,187 


42 


1,963 


9,504 


1.23 


16,624 


898,756 


66 


1,135 


1.85 


37,929 


2,779,027 


25 


1,053 


9.263 


1.36 


1,622 


89,482 


12 


621 


1.81 


2,810 


191,530 


3 


82 


5,320 


1.47 


18,004 


1,316,993 


72 


1,524 


1.37 


8,230 


698,920 


15 


281 


3,883 


1.18 


4,660 


207,980 


21 


825 


2.24 


4,181 


163,080 


3 


154 


4,530 


2.56 


24,949 


1,662,200 


78 


1,776 


1.50 


17,259 


1,171,960 


26 


580 


3,756 


1.47 


45,801 


3,474,168 


148 


1,956 


1.32 


33.415 


2,918,292 


33 


1,266 


7,369 


1.15 


1,452 


84,160 


16 


438 


1.73 


2.057 


145,780 


2 


89 


6,074 


1.41 


1,117 


63,520 
148,100 


11 

25 


481 
494 


1.76 
2.56 














3,797 


3.363 


172,800 


4 


105 


3,600 


1.95 


2,100 


95,255 


23 


345 


2.20 


254 


4,800 


1 


13 


400 


5.30 


12,900 


803,064 


70 


956 


1.61 


10,342 


768,661 


10 


293 


6,406 


1.35 


12,347 


700,625 


49 


1,192 


1.76 


20,530 


1,307,420 


18 


603 


6,053 


1.57 


56,112 


2,748,618 


169 


1,441 


2.04 


39,942 


2,770,076 


16 


1,200 


8,878 


1.44 


111,085 


7,224,201 


327 


1.841 


1.54 


78,068 


6,486,823 


52 


2,445 


10,396 


1.20 


134,040 


10,443,481 


269 


3,235 


1.28 


881,876 


116,630,481 


37 


25,140 


262,681 


0.76 


24,805 


1,415,922 


125 


944 


1.75 


6,559 


390,750 


15 


215 


2,171 


1.68 


336,781 


27,702,661 


543 


4,251 


1.22 


239,052 


24,283,672 


48 


7,413 


42,159 


0.98 


19,773 


1,784,364 


56 


2,655 


1.11 


12.733 


1,593,570 


9 


399 


14,755 


0.80 


291,271 


21,276,258 


1,087 


1,631 


1.37 


128,517 


11,496,314 


139 


3,825 


6,892 


1.12 


2,412,287 


158,004,178 


6,144 


2,143 


1.53 


1,608,091 


154,744,758 


1.211 


53.599 


10.649 


1.04 


16,135 


777,246 


103 


629 


2.08 


4,800 


242,769 


13 


167 


1,556 


1.98 


5,574 


344.824 


34 


845 


1.62 


4,185 


205,850 


5 


169 


3,431 


2.03 


258,532 


14,013,271 


792 


1,474 


1.84 


706,290 


79,726,318 


197 


17,066 


33,725 


0.89 


1.552 


66,440 


14 


395 


2.34 


7,597 


741,362 


33 


170 


1.872 


1.02 


4,911 


211,352 


40 


440 


2.32 


3,899 


274,626 


5 


89 


4.577 


1.42 


36,504 


2,392,523 


122 


1,634 


1.53 


23,896 


1,656,831 


42 


1,049 


3,287 


1.44 


162,324 


12,482,211 


66C 


1,576 


1.30 


300,976 


31,194,513 


141 


11,804 


18,436 


0.96 


4,851 


305,443 


19 


1,340 


1.59 


2,756 


180,168 


3 


93 


5,005 


1.53 


408,809 


34,233,406 


1,625 


1,756 


1.19 


1,359,260 


174,066,763 


271 


43,219 


53,526 


0.78 



258 



Municipal Electrical Service 

Municipal Electrical 

CUSTOMERS, REVENUE, 

for the Year Ended 





Popula- 
tion 


Total 
customers 


Peak 
load 
Decem- 
ber 
1960 


Residential service 
(including flat-rate water-heaters) 




Municipality 


Revenue 


Consumption 


Cus- 
tomers 


>, a 2 

c 3 u 
o c >- 


Av- 
erage 
cost 

per 
kwh 


^Ottawa (including Eastview 

and Rockcliffe Park).. . 

Otterville 


No. 

281,542 

726 

17,657 

744 

1,526 

5,778 
1,136 
6,057 
4,856 
5,831 

46,424 
3,649 
1.764 

§200 
5.062 

484 

2.714 

42,581 

716 

*496 

15,024 
6,564 
3,325 
3,096 
1.723 

8,072 

1,016 

2,247 

795 

*1,442 

1,036 

5,235 

11,338 

155 

438 

448 
1,198 
2,377 
1,740 
8,409 


No. 

87,629 

287 

6,125 

327 

625 

1,973 
498 
1,978 
1,415 
1,994 

14,757 

1.309 

487 

106 
1,798 

195 
807 
13,673 
462 
515 

4,614 

2,774 
1.079 
1.558 
1.064 

2,824 
495 
833 
319 

1,137 

359 

1,745 

3,360 

62 

174 

183 
452 

1,063 
331 

2,716 


kw 

188,731 

449 

12,600 

478 

1.296 

3,660 
911 
2,306 
2,809 
4,175 

38,533 

1,768 

899 

136 
4,013 

664 

4.172 

43,670 

235 

353 

6,708 
10,974 
1,668 
2,116 
1,169 

7,987 
1,364 
1,572 
306 
1.017 

707 

3,722 

9,332 

59 

282 

398 
561 

1,611 
924 

4,564 


$ 

4,404.803 

13.642 

339,828 

13,929 

30,165 

103,131 
26,954 

117,994 
62.104 
91.819 

883.187 
49,421 
40,039 

5,845 
103,654 

10,866 
26,597 
718,651 
18,398 
28,013 

189,599 
155,846 
82.413 
47,525 
46,347 

177,682 

18,274 

44,071 

9,542 

51,141 

24,823 

86,065 

205,856 

2,581 

8.623 

12,032 
42,007 
64,293 
21,157 
139,115 


kwh 

581,874,068 

1,177,473 

32,079,255 

1,078,530 

2,800,213 

7.825,456 
2.022.741 
9.537,790 
6,439,324 
9,290,059 

84,046.544 
3.106.509 
2.719.900 

359.044 
9.664,406 

949,076 

2,390,860 

85,673,732 

676,495 

1,521,829 

14,166,046 
14,683,262 
6,319,768 
3,367,592 
3,104.345 

15,508.832 

1.474,799 

4,210,965 

630,830 

3.401,240 

1,754.421 

9,336.628 

17.368,935 

116,685 

751,710 

1.124,782 
1,429,520 
3,707,358 
2,441,419 
13,290,852 


No. 

76,590 

233 

5,681 

255 
510 

1.714 
444 
1,806 
1,301 
1,816 

13,099 

1,101 

453 

76 

1,478 

181 
731 
11,992 
434 
449 

4,046 

2,615 

1,015 

1,330 

879 

2,629 
482 
784 
289 

1,078 

284 

1,616 

3.102 

55 

132 

177 
419 
850 
310 
2,468 


kwh 

633 

421 
471 
352 
458 

380 
380 
454 
412 
426 

535 
235 
500 

394 

545 

437 
273 
595 
130 
282 

292 
468 
519 
211 
294 

492 
255 
448 
182 
263 

515 
481 
467 
177 

475 

536 
284 
363 
656 
449 


0.76 
1.16 


fOwen Sound 


1.06 


Paisley 


1.29 


Palmerston 


1.08 


Paris 


1.32 


<#>Parkhill 


1.33 


<#> Parry Sound 


1.24 


#Penetanguishene 


0.96 


# Perth 


0.99 


Peterborough 


1.05 


<^Petrolia 


1.59 


<#> Pickering 


1.47 


<#fPickle Lake Landing 

Townsite 


1.63 


<@>Picton 


1.07 


<i>Plattsville 


1.14 


#> Point Edward 


1.11 


Port Arthur 


0.84 


#Port Burwell 


2.72 


<^fPort Carling 


1.84 


Port Colborne 


1.34 


#Port Credit 


1.06 


#>Port Dalhousie 


1.30 


Port Dover 


1.41 


Port Elgin 


1.49 


#Port Hope 


1.15 


#Port McNicoll. . . . 


1.24 


#Port Perry 


1.05 


<$>Port Rowan 


1.51 


#>Port Stanley 


1.50 


<#>tPowassan 


1.41 


<#>Prescott 


0.92 


#>Preston 


1.19 


<^Priceville 


2.21 


Princeton 


1.15 


<i>Queenston 


1.07 


^Rainy River 


2.94 


#fRed Lake Twp 


1.73 


#Red Rock 


0.87 


^Renfrew 


1.05 







For explanation of symbols see page 264. 



Statement D 



259 



Utilities and Local Systems 
AND CONSUMPTION 
December 31, I960 



Commercial service 
(including flat-rate water-heaters) 




Industrial power 


SERVICE 












a to 


Av- 








CO >> 

35 


c fc 


Av- 








•2 i 


erage 








"s §-8 


1 E 


erage 


Revenue 


Consumption 


Cus- 
tomers 


Monthly 
consumpi 
per custo 


cost 
per 
kwh 


Revenue 


Consumption 


Cus- 
tomers 


Average 
tomers'm 
loads bill 


Monthly 
consumpi 
per custo 


cost 
per 
kwh 


$ 


kwh 


No. 


kwh 


i 


$ 


kwh 


No. 


kw 


kwh 


i 


4,933,466 


415,216,004 


10,838 


3,193 


1.19 


473,813 


43,063,870 


201 


15,924 


17.854 


1.10 


5,110 


274,551 


47 


487 


1.86 


2,324 


96,242 


7 


77 


1.146 


2.41 


126,858 


9,517,444 


306 


2,592 


1.33 


142,176 


12,516,404 


138 


5,653 


7.558 


1.14 


7,953 


408,380 


65 


524 


1.95 


3,294 


253,291 


7 


85 


3.015 


1.30 


14,479 


901,011 


95 


790 


1.61 


11,100 


823,806 


20 


474 


3,433 


1.35 


33,462 


2,291,611 


223 


856 


1.46 


55,989 


4,929,291 


36 


2,194 


11,410 


1.14 


13,019 


692,155 


41 


1,407 


1.88 


9,733 


480,795 


13 


314 


3,082 


2.02 


55,607 


3,243,289 


149 


1,331 


1.71 


20,449 


1,570,593 


23 


652 


5,691 


1.30 


21,720 


1,860,068 


90 


1,722 


1.17 


37,247 


4,167,752 


24 


1,404 


14,471 


0.89 


39,012 


3,168,325 


135 


1,956 


1.23 


43,018 


4,224,687 


43 


1,806 


8,187 


1.02 


435.597 


27,689,438 


1,410 


1,636 


1.57 


594,610 


72,717,747 


248 


20,189 


24,435 


0.82 


32,199 


1,567,968 


173 


755 


2.05 


35,335 


1,688,085 


35 


923 


4,019 


2.09 


9,364 


644,171 


30 


1,789 


1.45 


4,641 


354,420 


4 


158 


7,384 


1.31 


2,490 


136,668 


29 


393 


1.82 


358 


11,980 


1 


12 


998 


2.99 


59,184 


4,105,324 


278 


1,231 


1.44 


20,080 


1,959,396 


42 


890 


3,888 


1.02 


1,600 


69,500 


11 


527 


2.30 


16,487 


1,607,295 


3 


411 


44,647 


1.03 


13,555 


983,990 


51 


1,608 


1.38 


121,513 


11,841,776 


25 


4,098 


39,473 


1.03 


413,937 


38,358,934 


1,622 


2,065 


1.08 


581,859 


68,750,884 


59 


24,243 


43,077 


0.85 


4,325 


185,172 


24 


643 


2.34 


723 


6,180 


4 


53 


129 


11.70 


14,908 


613,242 


60 


852 


2.43 


1,463 


114,090 


6 


55 


1,585 


1.28 


109,579 


6,034,019 


488 


1,030 


1.82 


80,813 


7,042,827 


80 


2,545 


7,336 


1.15 


68,993 


5,061,354 


148 


2,850 


1.36 


289,980 


45,041,498 


11 


6,450 


341,223 


0.64 


11,581 


711,344 


47 


1,261 


1.63 


10,554 


572,296 


17 


314 


2,805 


1.84 


.28,417 


1,768,025 


192 


767 


1.61 


45,210 


4,012,348 


36 


1.393 


9,288 


1.13 


25,227 


1,238,404 


171 


604 


2.04 


13,101 


715,867 


14 


338 


4,261 


1.83 


54,537 


3,825,281 


145 


2,198 


1.43 


157,301 


16,108,682 


50 


4,724 


26,848 


0.98 


2,510 


146,800 


11 


1,112 


1.71 


30,859 


1,649,040 


2 


995 


68,710 


1.87 


11,106 


817,964 


36 


1,893 


1.36 


5,967 


400,858 


13 


246 


2,570 


1.49 


5,632 


350,565 


27 


1,082 


1.61 


713 


27,145 


3 


26 


754 


2.63 


11,038 


636,690 


42 


1,263 


1.73 


7,852 


329,750 


17 


339 


1,616 


2.38 


10,453 


547,529 


71 


652 


1.91 


801 


22,722 


4 


24 


379 


3.53 


27,620 


1,922,854 


93 


1,723 


1.44 


40,868 


3,575.776 


36 


1,534 


8,277 


1.14 


49,282 


3,045,278 


152 


1,670 


1.62 


234,332 


19,323,275 


106 


7,913 


15,191 


1.21 


828 


44,795 


7 


533 


1.85 














3,550 


185,893 


39 


397 


1.91 


1,441 


58,745 


3 


54 


1,632 


2.45 


4,908 


376,332 
398,170 


6 

25 


3,920 
1,327 


1.30 
3.34 














13,287 


3,779 


174,906 


8 


92 


1,822 


2.16 


43,567 


2,594,475 


203 


1,065 


1.68 


10,943 


414,361 


10 


269 


3,453 


2.64 


13,084 


1,068,817 


20 


4,453 


1.22 


1,541 


172,000 


1 


56 


14,333 


0.90 


52,551 


3,937,134 


185 


1.773 


1.33 


79,564 


7,872,572 


63 


3,020 


10,413 


1.01 



260 



Municipal Electrical Service 



Municipal Electrical 

CUSTOMERS, REVENUE, 

for the Year Ended 



Municipality 



Popula- 
tion 



Total 
customers 



Peak 
load 
Decem- 
ber 
1960 



Residential service 
(including flat-rate water-heaters) 



Revenue 



Consumption 



Cus- 
tomers 



a 2 

e 2 



u a 



^Richmond 

<$>Richmond Hill 

Ridgetown 

<$>Ripley 

<#>Riverside 

<i> Rockland 

<$>Rockwood 

Rodney 

#Rosseau 

#Russell 

St. Catharines 

#St. Clair Beach 

<#>St. George 

St. Jacobs 

<|>St. Mary's 

St. Thomas 

#Sandwich East Twp 

<§>Sandwich West Twp 

<|>Sarnia 

<$>Scarborough Twp 

<$>Schreiber Twp 

<#>Seaforth 

#Shelburne 

<t>Simcoe 

Sioux Lookout 

Smith's Falls 

Smithville 

Southampton 

#tSouth Porcupine Townsite 
#Springfield 

Stamford Twp 

Stayner 

<#>Stirling 

<$>Stoney Creek 

<t>Stouffville 

Stratford 

•#Strathroy 

Streetsville 

^Sturgeon Falls 

Sudbury 



No. 

1.183 

16,095 

2,612 

442 

17,549 

2,919 
897 

1,067 
228 
556 

41,163 
1,416 

754 

715 

4,509 

22,348 
21,864 
27,786 
49,089 
197,969 

2,165 
2,260 
1,247 
8,453 
2,645 

9,082 

835 

1,716 

§5,600 

536 

29,655 
1,624 
1,328 
6,130 

3,052 

20,432 
4,844 
4,979 
6,288 

77,356 



No. 

331 
4,712 
1,046 

217 
5,346 

736 
291 
445 
127 
209 

14,105 

429 

308 

227 

1,646 

7,033 

6,191 

7,862 

15,419 

59,815 

647 
865 
570 
3,139 
943 

3,330 

375 

1,158 

1,893 

182 

8,931 

648 

536 

1,952 

1,066 

6,978 
1,807 
1,445 
1,613 
22,216 



kw 

700 

10,920 

1,425 

310 

8,074 

1,191 
448 
578 
111 
358 

42,210 

648 

575 

476 

9,700 

14,860 
7,183 

13,311 
132,813 
151,177 

1,428 
1,842 
872 
8,071 
1,813 

7,692 

607 

1,034 

2,605 

269 

18,212 

1,127 

975 

4,139 

2,198 

15,928 
3,579 
3,419 
2,672 

44.831 



$ 
22,000 

347,468 
31,477 
10,402 

288,579 

37,209 
17,580 
13,021 
4,895 
8,866 

779,145 
30,459 
10,739 
12,560 

101,944 

374,790 
364,872 
557,320 
745,006 
4,212,528 

37,021 
42,669 
26,668 
116,316 
70,537 

168,551 
12,984 

39,773 
96,511 

8,217 

587,156 
33,631 
28,061 

135,841 

74,514 

426,606 

87,743 

97,340 

97,199 

1,444,257 



kwh 

1,824,716 
26,686,920 

2,197,365 

857,590 

20,487,724 

3,133,784 

1,377,110 

1,051,070 

276,460 

914,080 

58,285,283 
1,944,131 
1,149,971 
1,052,351 
8,504,066 

30,126,086 
16,414,113 
31,577,911 
55,923,697 
359,763,818 

4,319,614 
3,758,415 
2,008,230 
11,300,780 
4,863,079 

16,598,180 

909,167 

2,894,420 

6,478,191 

716,780 

45,934,303 
2,594,928 
2,465,551 

12,345,320 
5,815,033 

37,437,191 

8,124,685 

7,078,997 

7,139,358 

124,278,030 



No. 
316 

4,485 
849 
196 

5,201 

697 
272 
353 
119 
192 

12,218 
413 

278 

182 

1,505 

6,201 

5,921 

7,464 

14,443 

56,934 

607 
769 
516 
2,795 
799 

2,846 

275 

1,019 

1,616 

172 

8,253 
524 
479 

1,850 
983 

6,164 
1,600 
1,283 
1,512 
20,011 



kwh 
481 
496 
216 
365 
328 

375 
422 
248 
194 
397 

398 
392 
345 
482 
471 

405 
231 
353 
323 

527 

593 
407 
351 
337 
507 

486 
276 
237 
334 
347 

464 
413 
429 
556 

505 

506 
438 
460 
393 
518 



For explanation of symbols see page 264. 



Statement D 



261 



Utilities and Local Systems 
AND CONSUMPTION 
December 31, 1960 



Commercial service 
(including flat-rate water-heaters) 




Industria 


L POWER 


SERVICE 












d b 


Av- 








35 


c b 


Av- 


Revenue 


Consumption 


Cus- 
tomers 


Monthly 
consumptio 
per customi 


erage 
cost 
per 
kwh 


Revenue 


Consumption 


Cus- 
tomers 


Average of 
tomers'mon 
loads billed 


Monthly 
consumptio 
per customi 


erage 
cost 
per 
kwh 


$ 


kwh 


No. 


kwh 


i 


% 


kwh 


No. 


kw 


kwh 


i 


7,069 


444,010 
6,700,175 


15 
175 


2,467 
3,191 


1.59 
1.55 














104,001 


88,673 


7,032,239 


52 


2,415 


11,270 


1.26 


25,873 


1,460,860 


167 


729 


1.77 


29,434 


1,795,490 


30 


896 


4,987 


1.64 


2,923 


167,600 


18 


776 


1.74 


1,931 


93,625 


3 


75 


2,601 


2.06 


41,151 


2,694,289 


114 


1,970 


1.53 


38,262 


2,378,434 


31 


1,368 


6,394 


1.61 


8,795 


538,219 


35 


1.281 


1.63 


1,684 


161,520 


4 


72 


3,365 


1.04 


3,615 


221,586 


18 


1,026 


1.63 


1,421 


58,000 


1 


41 


4,833 


2.45 


7,784 


468,302 


81 


482 


1.66 


7,059 


304,440 


11 


254 


2,306 


2.32 


1,981 


102,332 


8 


1,066 


1.94 














1,934 


136,950 


14 


815 


1.41 


609 


36,570 


3 


36 


1,016 


1.67 


474,871 


27,655,408 


1,633 


1,411 


1.72 


1,058.670 


110,172,797 


254 


30,951 


36,146 


0.96 


3,422 


189,580 


10 


1,580 


1.81 


2,854 


111,500 


6 


107 


1,549 


2.56 


4,904 


390,924 


23 


1,416 


1.25 


6.278 


551,445 


7 


204 


6,565 


1.14 


7,657 


398,690 


36 


923 


1.92 


5.611 


183,738 


9 


239 


1,701 


3.05 


24,649 


1,536,267 


96 


1,334 


1.60 


343,674 


48,997,194 


45 


8,861 


90.736 


0.70 


180,226 


13,146,585 


722 


1,517 


1.37 


281.112 


29,965,679 


110 


9,151 


22,701 


0.94 


82,201 


3,709,608 


203 


1,523 


2.22 


132.051 


6,185,160 


67 


3,046 


7,693 


2.13 


172,603 


9,713,780 


329 


2,460 


1.78 


115,412 


7,049,116 


69 


2,668 


8,513 


1.64 


360,341 


24,218,109 


806 


2,504 


1.49 


4,879,498 


825,395,334 


170 


105,769 


404,606 


0.59 


1,389,214 


103,496,378 


2,566 


3,361 


1.34 


1,453,237 


145,686,252 


315 


42,104 


38,541 


1.00 


10,703 


911,467 


37 


2,053 


1.17 


3,450 


421,760 


3 


111 


11,716 


0.82 


20,459 


1,252,420 


75 


1,392 


1.63 


18,489 


1,381,344 


21 


618 


5.482 


1.34 


14,317 


810,840 


42 


834 


1.77 


6,438 


344,050 


12 


250 


2,389 


1.87 


95,415 


7,044,900 


249 


2,358 


1.35 


155,338 


15,997,316 


95 


5,223 


14,033 


0.97 


39,602 


1,599,549 


127 


1,050 


2.48 


14,097 


1,198,253 


17 


308 


5,874 


1.18 


91,149 


7,053,172 


428 


1,373 


1.29 


64,199 


6,740,836 


56 


2,357 


10,031 


0.95 


11,368 


545,618 


85 


535 


2.08 


13,740 


718,244 


15 


428 


3,990 


1.91 


17,997 


884,370 


126 


585 


2.04 


16,660 


996,530 


13 


471 


6,388 


1.67 


44,917 


2,516,921 


270 


827 


1.78 


4,693 


339,856 


7 


175 


1,205 


1.38 


1,359 


101,170 


7 


1,204 


1.34 


1,436 


51,475 


3 


92 


1,430 


2.79 


204,583 


9,684,138 


576 


1,401 


2.11 


211,978 


17,706,440 


102 


6,813 


14.466 


1.20 


16,122 


791,970 


106 


623 


2.04 


10,238 


728,847 


18 


342 


3,374 


1.40 


8,464 


503,156 


40 


1,048 


1.68 


5,838 


407,535 


17 


230 


1,998 


1.43 


33,153 


2,475,034 


84 


2,455 


1.34 


11,118 


850,900 


18 


407 


3,939 


1.31 


28,878 


1,563,426 


68 


1,416 


1.85 


11,931 


593,145 


15 


359 


3.295 


2.01 


188,040 


12,541,650 


655 


1,596 


1.50 


246,019 


22,760,933 


159 


8,428 


11.929 


1.08 


43,070 


2,907,806 


152 


1,182 


1.48 


56,650 


4,115,721 


55 


2,063 


6,236 


1.38 


32,212 


1,811,005 


134 


1,126 


1.78 


38,867 


3,649,573 


28 


1,095 


10,862 


1.06 


38,871 


2,392,148 


85 


2.345 


1.62 


4,855 


406,795 


16 


154 


2,119 


1.19 


696,722 


41,162,038 


1.962 


1,748 


1.69 


200,014 


15,840,914 


243 


6,329 


5,432 


1.26 






262 



Municipal Electrical Service 



Municipal Electrical 

CUSTOMERS, REVENUE, 

for the Year Ended 



Municipality 



Popula- 
tion 





Peak 






load 




Decem- 


Total 


ber 


customers 


1960 


No. 


kw 


262 


411 


296 


378 


890 


1,004 


3,528 


6,423 


235 


480 


510 


912 


1,337 


1,543 


360 


715 


428 


1,416 


352 


779 


442 


673 


315 


502 


534 


748 


534 


875 


137 


280 


38 


41 


103 


145 


2,566 


11,650 


1,053 


1,356 


2,450 


5,919 


9,598 


15,943 


208,956 


611,872 


15,130 


55,004 


271 


464 


4,078 


15,264 


624 


1,150 


888 


1.747 


544 


657 


494 


376 


1,295 


2,928 


2,744 


7,037 


148 


199 


236 


332 


1,038 


276 


589 


1,175 


823 


1,099 


6,445 


17,040 


524 


1,236 


443 


298 


155 


182 



Residential service 
(including flat-rate water-heaters) 



Revenue 



Consumption 


Cus- 
tomers 


Monthly 
consumption 
per customer 


kwh 


No. 


kwh 


1,066,850 


239 


372 


964,150 


267 


301 


2,674,677 


726 


307 


19,007,645 


3,364 


471 


862,320 


211 


341 


2,320,052 


398 


486 


3,822,308 


1,276 


250 


1,379,220 


323 


356 


4,756,102 


400 


991 


1,923,301 


332 


483 


1,058,290 


388 


227 


1,158.790 


286 


338 


1,754,210 


440 


332 


1,599,219 


433 


308 


692,089 


128 


451 


140,039 


27 


432 


394,920 


90 


366 


10,734,023 


2,287 


391 


2,237,536 


926 


201 


8,488,345 


2,151 


329 


42,247,846 


8,291 


425 


937,716,480 


175,156 


446 


102,675,231 


14,384 


595 


1,263,230 


246 


460 


23,551,276 


3,744 


532 


2,914,520 


556 


437 


4,333,300 


804 


449 


1,636,424 


497 


274 


1,120,860 


456 


205 


5,754,176 


1,184 


405 


6,768,829 


2,442 


231 


391,916 


114 


286 


842,996 


227 


309 


1,138,370 


834 


114 


3,335,714 


498 


558 


2,828,842 


786 


300 


38,890,633 


5,885 


551 


2,167,773 


469 


394 


830,575 


410 


169 


401,562 


128 


261 



^Sunderland 

<§>Sundridge 

Sutton 

<$>Swansea 

<#>Tara 

Tavistock 

#Tecumseh 

#Teeswater 

^Terrace Bay Twp 

•#>Thamesford 

<#>Thamesville 

#Thedford 

<^Thessalon 

Thornbury 

<#Thorndale 

#>fThornloe 

Thornton 

<§>Thorold 

<#Tilbury 

<$>Tillsonburg 

<$>tTimmins (including 

Schumacher) 

Toronto (including Leaside) 

<$>Toronto Twp 

<$>Tottenham 

^Trenton 

<|>Tweed 

#Uxbridge 

<$>Vankleek Hill 

Victoria Harbour 

<$>Walkerton 

<#Wallaceburg 

Wardsville 

^Warkworth 

•#Wasaga Beach 

Waterdown 

#Waterford 

Waterloo 

<#. Watford 

Waubaushene 

Webbwood 



No. 

611 

765 

1,405 

9,529 

506 

1,222 
4,416 

895 
1,900 

984 

1,040 

738 

1,717 

1,161 

416 

194 

289 

8,602 

3,070 

6,542 



31,441 

657,233 

59,983 

781 

12,314 

1,717 
2.369 
1.690 
999 
3,835 

8,029 

313 

524 

*414 

1,834 

2,155 
20,562 

1,235 

§1,400 

590 



$ 

11,660 
14,395 
32,850 
180,125 
10,079 

27,848 
63,987 
15,909 
33,922 
26,382 

15,119 
13,119 
31,164 
24,570 
9,460 

2,197 
5,256 

134,138 
35,317 

107,023 



579,146 

11,753,682 

1,155,504 

14,388 

210,183 

24,367 
45,122 
24,989 
19,239 
64,701 

84,272 

5,198 

9,906 

28,117 

40,360 

41,323 
395,652 
26,107 
14,522 
10,947 



For explanation of symbols see page 264. 



Statement D 



263 



Utilities and Local Systems 
AND CONSUMPTION 
December 31, 1960 



Commercial service 
(including flat-rate water-heaters) 




Industrial power 


SERVICE 












c fc 


Av- 








35 


C \A 


Av- 


Revenue 


Consumption 


Cus- 
tomers 


Monthly 
consumptio 
per custom* 


erage 
cost 
per 
kwh 


Revenue 


Consumption 


Cus- 
tomers 


Average of 
tomers'mon 
loads billed 


Monthly 
consumptio 
per custom< 


erage 
cost 
per 
kwh 


$ 


kwh 


No. 


kwh 


i 


$ 


kwh 


No. 


kw 


kwh 


i 


3.440 


173,550 


19 


761 


1.98 


3,080 


207,030 


4 


100 


4,313 


1.49 


7.614 


394,090 


26 


1,263 


1.93 


1,271 


57,010 


3 


40 


1,584 


2.23 


21,507 


1,282,092 


152 


703 


1.68 


5,265 


270.700 


12 


169 


1,880 


1.94 


60.212 


4,668,043 


142 


2,739 


1.29 


61,355 


7,488,566 


22 


1,906 


28,366 


0.82 


2,918 


172,520 


18 


799 


1.69 


6,297 


572.160 


6 


163 


7,947 


1.10 


11,084 


543,327 


103 


440 


2.04 


9,267 


502,724 


9 


286 


4,655 


1.84 


13,261 


774,711 


50 


1,291 


1.71 


10,574 


740,768 


11 


318 


5,612 


1.43 


5,317 


305,265 


29 


877 


1.74 


11,358 


943,370 


8 


346 


9,827 


1.20 


14,724 


1.377.860 


26 


4,416 


1.07 


4,994 


704,000 


2 


132 


29,333 


0.71 


3,561 


186.804 


15 


1,038 


1.91 


10,109 


826,383 


5 


224 


13,773 


1.22 


8.874 


580.624 


38 


1,273 


1.53 


16,464 


816,876 


16 


608 


4,255 


2.02 


4.152 


268,500 


24 


932 


1.55 


2,889 


283,350 


5 


85 


4,723 


1.02 


19.802 


949,516 


87 


909 


2.09 


3,730 


262,365 


7 


90 


3,123 


1.42 


12,459 


570,150 


83 


572 


2.19 


15,112 


989,582 


18 


560 


4,581 


1.53 


1,111 


53,196 


6 


739 


2.09 


2,093 


79,754 


3 


73 


2,215 


2.62 


1,306 


64,137 


11 


486 


2.04 














1,280 


50,600 
2,984,886 


13 
233 


324 
1,068 


2.53 
1.64 














48,980 


350,518 


50,487,075 


46 


9,286 


91,462 


0.69 


24,268 


1,448,978 


101 


1,196 


1.67 


24,385 


1,073,240 


26 


960 


3.440 


2.27 


89,582 


6,138.122 


247 


2,071 


1.46 


63,222 


5,337,891 


52 


1,976 


8,554 


1.18 


284,426 


16,525,898 


1,275 


1,128 


1.72 


32,137 


1,692,160 


32 


792 


1,640 


1.90 


9,259,394 


629,701.930 


26,802 


1,958 


1.47 


15,301,553 


1,521,639,865 


6,998 


411,561 


18,120 


1.01 


374,713 


26,261,811 


578 


3,786 


1.43 


1,409,499 


167,561,038 


168 


35,622 


83,116 


0.84 


4,334 


215,965 


20 


486 


2.01 


1,926 


179,868 


5 


58 


2,998 


1.07 


85,481 


7,427,900 


249 


2,016 


1.15 


354,24? 


51,972,275 


85 


10,918 


50,953 


0.68 


10,322 


868,433 


54 


1,340 


1.19 


6,759 


659,144 


14 


309 


3,923 


1.03 


14,987 


945,267 


60 


1,313 


1.59 


23.247 


1,262,763 


24 


820 


4,385 


1.84 


8,451 


463,079 


36 


1,072 


1.82 


4,534 


139,189 


11 


219 


1,054 


3.26 


4,554 


196,480 


36 


455 


2.32 


539 


34,560 


2 


12 


1,440 


1.56 


31,161 


1.979,152 


92 


1,793 


1.57 


30,358 


2,480,274 


19 


983 


10,878 


1.22 


58,593 


4,399,766 


213 


1,721 


1.33 


243,333 


30,537,699 


89 


7,359 


28,593 


0.80 


5,969 


312,850 


34 


767 


1.91 














1,985 


116,030 


9 


1,074 


1.71 














25,341 


1,108,589 


203 


455 


2.29 


336 


8,000 


1 


13 


667 


4.19 


12,817 


689,680 


74 


777 


1.86 


4,500 


278,549 


17 


160 


1,365 


1.62 


9,379 


509,540 


25 


1,698 


1.84 


11,343 


533,160 


12 


400 


3,703 


2.13 


183,416 


11,680.796 


467 


2,084 


1.57 


261,140 


24,993,619 


93 


7,295 


22,396 


1.04 


13,122 


719.869 


43 


1,132 


1.82 


25,888 


1.995,003 


12 


785 


13,854 


1.30 


3,825 


201,410 


30 


559 


1.90 


2,308 


73,160 


3 


64 


2,032 


3.15 


5,497 


166,486 


26 


534 


3.30 


631 


43,800 


1 


13 


3,650 


1.44 



264 



Municipal Electrical Service 

Municipal Electrical 

CUSTOMERS, REVENUE, 

for the Year Ended 



Municipality 



Popula- 
tion 





Peak 






load 




Decem- 


Total 


ber 


customers 


1<;60 


No. 


kw 


5,496 


14,385 


278 


469 


497 


588 


1,835 


4,014 


428 


934 


3,398 


8,461 


293 


394 


490 


851 


3,732 


11,476 


230 


487 


791 


1,370 


147 


254 


558 


1,288 


120 


73 


37,142 


81,014 


1,045 


2,266 


754 


2,164 


6,798 


17,988 


197 


242 


330 


369 


40,423 


67,987 


304 


452 



Residential service 
(including flat-rate water-heaters) 



Revenue 



Consumption 



Cus- 
tomers 



E » 



<j a 



Av- 
erage 
cost 
per 
kwh 



Welland 

Wellesley 

<# Wellington 

<$> West Ferris Twp 
#West Lome 

■#> Weston 

<$> West port 

Wheatley 

#Whitby 

#t White River. . .. 

■#Wiarton 

Williamsburg. . . 

Winchester 

#> Windermere .... 
#> Windsor 

#Wingham 

<#Woodbridge .... 

# Woodstock 

Woodville 

#Wyoming 

#York Twp 

Zurich 



No. 

17,556 

670 

1,002 

5,096 

1,077 

9,419 

693 

1,337 

12,501 

818 

2,038 

336 

1,379 

*119 

116,160 

2,770 

2,293 

19,923 

422 

876 

123,457 
737 



$ 

190,665 
14,121 
17,986 

127,925 
18,003 

196,760 
11,451 
19,008 

224,036 
22,907 

35,773 
4,615 

26,621 

4,968 

1,408,046 

54,692 

50,249 

418,067 

8,895 

9,980 

2,029,551 
14,712 



kwh 
15,370,986 
1,001,452 
1,813,120 
8,841,126 
1,195,754 

17,959,095 
1,074,790 
1,245,154 

19,625,292 
883,812 

3,519,480 
521,527 

2,167,560 

292,350 

125,232,323 

5,607,010 

4,641,625 

37,298,668 

584,086 

745,490 

212,262,622 
1,008,360 



No. 

4,702 

218 

465 

1,695 

383 

3,102 
267 
399 

3,408 
212 

707 
108 
446 
108 
34,335 

930 
698 
6,296 
156 
299 

38,670 
244 



kwh 
272 
383 
325 
435 
260 

489 
335 
260 
480 
347 

415 
402 
405 
226 
304 

502 
554 
494 
312 
208 

457 
344 



i 

1.24 
1.41 
0.99 
1.45 
1.51 

1.10 
1.07 
1.53 
1.14 
2.59 

1.02 
0.88 
1.23 
1.70 
1.12 

0.98 
1.08 
1.12 
1.52 
1.34 

0.96 
1.46 



<§> New municipal retail rate structure 

<%> and with small commercial customers transferred to residential billing 

t Local system 

* Excluding summer population 

§ Estimated 



Statement D 



265 



Utilities and Local Systems 
AND CONSUMPTION 
December 31, 1960 





Commercial service 


















(including flat-rate water-heaters) 






Industrial power service 












5 & 


Av- 








00 J^ 1 

3~ 


c fc 


Av- 








•2 6 


erage 








o o-g 


•2 E 


erage 






Cus- 


hly 
mpi 

.isto 


cost 






Cus- 


«, S 3 

60 to X3 


>> a ° 

3 C « 


cost 


Revenue 


Consumption 


tomers 


Mont 
consu 
per ci 


per 
kwh 


Revenue 


Consumption 


tomers 


Aver; 

tomei 
loads 


Mont 
consu 
per ci 


per 
kwh 


$ 


kwh 


No. 


kwh 


i 


$ 


kwh 


No. 


kw 


kwh 


i 


160,270 


10,083,055 


662 


1,269 


1.59 


372,623 


40,793,395 


132 


10,756 


25,753 


0.91 


6,166 


322,340 


53 


507 


1.91 


2,527 


115,617 


7 


82 


1,376 


2.19 


3,581 


229,572 


17 


1,125 


1.56 


4,496 


240,781 


15 


187 


1,338 


1.87 


44,131 


2,534,566 


124 


1,703 


1.74 


44,014 


5,023,323 


16 


1,058 


26,163 


0.88 


9,605 


496,733 


34 


1,217 


1.93 


26,633 


1,855,610 


11 


665 


14,058 


1.44 


130,998 


9,135,034 


259 


2,521 


1.43 


158,261 


14,717,982 


37 


4,707 


21,330 


1.08 


6,401 


430,720 


24 


1,496 


1.49 


142 


3,073 


2 


10 


128 


4.63 


18,493 


899,655 


76 


986 


2.06 


17,547 


852,200 


15 


499 


4,734 


2.06 


77,050 


5,291,300 


2 73 


1,615 


1.46 


215,406 


24,854,813 


51 


6,541 


40,612 


0.87 


9,271 


313,027 


17 


1,534 


2.96 


6,470 


458,820 


1 


82 


38,235 


1.41 


17,254 


1,175,655 


67 


1,462 


1.47 


10,711 


748,534 


17 


361 


3,669 


1.43 


3,933 


273,846 


38 


601 


1.44 


259 


15,830 


1 


6 


1,319 


1.64 


13,822 


851,170 


101 


702 


1.62 


22,675 


2,275,148 


11 


574 


17,236 


1.00 


2,834 


169,360 


12 


1,176 


1.67 














855,446 


65,276,683 


2,047 


2,657 


1.31 


1,879,491 


172,216,246 


760 


65,467 


18,883 


1.09 


21,987 


1,434,805 


82 


1,458 


1.53 


35,742 


2,767,252 


33 


1,257 


6,988 


1.29 


17,617 


1,047,437 


44 


1,984 


1.68 


39,485 


3,400,341 


12 


1,177 


23,613 


1.16 


138,690 


10,068,614 


360 


2,331 


1.38 


381,975 


39,881,910 


142 


11,907 


23,405 


0.96 


3,528 


142,220 


39 


304 


2.48 


1,138 


35,670 


2 


33 


1,486 


3.19 


4,309 


276,521 


24 


960 


1.56 


8,107 


380,590 


7 


301 


4,531 


2.13 


497,346 


40,545,018 


1,228 


2,751 


1.23 


649,327 


68,827,149 


525 


23,053 


10,925 


0.94 


9,368 


381,856 


55 


579 


2.45 


1,256 


63,800 


5 


33 


1,063 


1.97 



NOTES 

The figures shown in italics under the heading "Monthly consumption per customer" 
have been estimated to allow for the transfer of small commercial customers to residential service 
and/or certain power service customers to commercial service. 

In accordance with revisions introduced into the Standard Interpretation of Rates in 1960, 
the service formerly designated as Domestic is now known as Residential Service and that formerly 
designated as Power Service is now known as Industrial Power Service. 



266 



Index 



LIST OF ABBREVIATIONS 



bhp — brake horsepower 

cfs — cubic feet per second 

C.L.C. — Canadian Labour Congress 

D.S. — Distributing Station 

G.S. — Generating Station 

hp — horsepower 

Jet. — Junction 

kv — kilovolt(s) 

kva — kilovolt-ampere(s) 

kvar — kilovar(s) 

kw — kilowatt(s) 

kwh — kilowatt-hour(s) 



M.E.U. — Municipal Electrical Utilities 
min — minimum 

— minute (20-min) 
N.O.P. — Northern Ontario Properties 
R.O.A. — Rural Operating Area 
R.P.D. —Rural Power District 
rpm — revolutions per minute 
S.O.S. — Southern Ontario System 
S.S. — Switching Station 
T.S. — Transformer Station 
Twp. — Township 



INDEX 

In the index all page references to tables or graphs are in italic type figures. The code letters 
refer to statements in the text as follows: 

A = Statements "A" and "B" — Financial Statements of the Municipal Electrical Utilities 

C = Statement "C" — Rates and Typical Bills for Electrical Service in Municipal Electrical 
Utilities and Local Systems 

D = Statement "D" — Customers, Revenue, and Consumption in Municipal Electrical Utilities 
and Local Systems 

P = Statement of the Allocation of the Cost of Primary Power 

5 = Statement of Sinking Fund Equity 



A 



A. \V. Manby T.S. and Service Centre, 

see Manby, A. W., T.S. 
Abitibi Canyon G.S.. .15, 62, 69, 77, 93, 136 
Abitibi Power & Paper Company, Limited.. 93 
Abitibi River, .vi, 5, 60, 61, 62, 69, 77, 93, 136 
Abrasives industry, power and energy 

supplied 43, 44 

Academy of Lighting Arts 57 

Accident prevention 89 

Accidents, electrical 57 

Accounting system of municipal 

electrical utilities 42 

Act, Provincial, to provide for the 

transmission of power 1 

Acton A 172 C 222 D 246 

P 108 S 128 
Adjustments, annual, to cost of power, 

see Cost of power 
Administrative buildings — ■ 

expenditures on 23 

see also N.O.P. & S.O.S.— assets, fixed 
Advances from Province of 

Ontario . 8, 29, 31, 36 

Aerial snraying 19 

Agnico Mines Limited 162 

Aguasabon G.S 16, 93, 136 

Ailsa Craig A 172 C 222 D 246 

P 108 S 128 

Air-blast circuit-breakers 17 

installed at Burlington T.S 66 

Air conditioning 56 

Ajax 54, A 172 C 222 D 246 

P 108 S 128 
Alexander G.S 93, 136 



Alexandria 55, A 172 C 222 D 246 

P 108 S 128 
Alfred A 172 C 222 D 246 

P 108 S 128 

Algoma District 72 

Alkalies in cement 82 

Allied Construction Council 88 

Alliston A 172 C 222 D 246 

P 108 S 128 
Allowance for providing step-down 

transformation 221 

Almonte A 173 C 222 D 246 

P 108 S 128 
Aluminum Company of Canada, Limited. 162 
Alvinston A 173 C 222 D 246 

P 108 S 128 
Amherstburg A 173 C 222 D 246 

P 108 S 128 

Analogue computer 80 

Analysis of primary loads by types of 

industry 43 

Ancaster Twp A 173 C 222 D 246 

P 108 S 128 

Anchors for towers in muskeg 78 

Annexation of rural areas by 

municipalities 45, 51 

Annual summary 5 

Apple Hill A 173 C 222 D 246 

P 108 S 128 

Appliance saturation survey 39 

Application of funds 24 

Architects, Ontario Association of 39 

Area offices built 63 

Arkona A 173 C 222 D 246 

P 108 S 128 



Index 



267 



Arnprior 55, A 173 C 222 D 246 

P 108 S 128 
Arthur A 173 C 222 D 246 

P 108 S 128 

Assets of the Commission 6, 23 

see also N.O.P. & S.O.S. 
Assets, fixed, of the Commission . . vi, 6, 23, 24 
see also N.O.P. & S.O.S., and Rural 
electrical service 
Assets of the municipal electrical 

utilities 166, 170-219 

Assistance, Provincial, for rural 

facilities 5, 23, 29, 31, 49 

Association of Municipal Electrical 

Utilities of Ontario 40, 89 

Athens A 173 C 222 D 246 

P 108 S 128 
Atikokan Twp A 216 C 222 D 246 

P 142 S 146 
Atomic Energy of Canada Limited. . . .62, 65 

Aubinadong River 72 

Auburn G.S 92 

Aurora A 174 C 222 D 246 

P 108 S 128 

Automatic equipment 87 

Avonmore A 174 C 222 D 246 

P 108 S 128 

Avro Aircraft Limited 162 

Award of Merit, National Safety Council.. 89 
Avlmer 57 , A 174 C 222 D 246 

P 108 S 128 
Ayr A 174 C 222 D 246 P 108 S 128 

B 

Baden A 174 C 222 D 246 P 108 S 128 

Bala C 222 D 246 

Balance sheets — Commission 28, 30 

municipal 170-219 

Bancroft 54, A 174 C 222 D 246 

P 108 S 128 

Bark Lake 72 

Barrett Chute G.S 92, 100 

Barrie 54, A 175 C 222 D 246 

P 108 S 128 

Barrie R.O.A 89 

Barry's Bay A 175 C 222 D 246 

P 108 S 128 
Base-metals mining industry, power and 

energy supplied 43, 44 

Bath A 175 C 222 D 246 P 108 S 128 

Beachburg 161 

Beachville A 175 C 222 D 246 

P 108 S 128 
Beamsville. .A 175 C 222 D 246 P 108 S 128 

Beardmore 56, C 222 D 246 

Beaverton. . .A 175 C 222 D 246 P 108 S 128 
Beaver Wood Fibre Company Limited. . . 162 
Beck, Sir Adam, -Niagara Generating 

Stations 14 

Beck, Sir Adam, -Niagara G.S. No. 1 . . . . 13, 

66, 92, 100 

Beck, Sir Adam, -Niagara G.S. No. 2 66, 

92, 100 

Pumping -Generating Station. ... 14, 82, 92 

Beeton . . 54, A 175 C 222 D 246 P 108 S 128 

Belle River A 175 C 222 D 246 

P 10S S 128 
Belleville 54, A 175 C 222 D 246 

P 108 S 128 

Code letters A, C, D, with page references, represent each of the statements so designated. P represents Cost 
ot Primary Power, and .S Sinking Fund Equity. 



Big Chute G.S 92 

Big Eddy G.S 92 

Bingham Chute G.S 93 

Bituminous coating for dowse tank 83 

Blenheim . . .A 176 C 222 D 246 P 108 S 128 

Blind River C 222 D 246 

Blind River T.S 76 

Bloomfield 54, A 176 C 222 D 246 

P 108 S 128 

Blvth A 176 C 222 D 246 P 108 S 128 

Bobcavgeon 54, ^ 176 C 222 D 246 

P 108 S 128 

Bolton A 176 C 222 I) 246 P 108 S 128 

Bonds issued by the 

Commission 24, 29, 31, 34-7 

Borrowing vi, 24 

Bothwell. . . A 176 C 222 D 246 P 108 S 128 
Bowmanville 54, A 177 C 224 D 248 

P 110 S 128 

Bowmanville R.O.A 45 

Bracebridge A 177 C 224 D 248 

P 110 S 128 
Bradford A 177 C 224 D 248 

P 110 S 128 
Braeside 55, A 177 C 224 D 248 

P 110 S 128 
Brampton 52, A 177 C 224 D 248 

P 110 S 128 
Brantford 51, A 177 C 224 D 248 

P 110 S 128 
Brantford Twp 51, ^4 177 C 224 D 248 

P 110 S 128 

Brantford T.S 66 

Brechin A 177 C 224 D 248 P 110 S 128 

Bridgeport A 177 C 224 D 248 

P 110 S 128 

Brigden A 178 C 224 D 248 P 110 S 129 

Brighton 54, A 178 C 224 D 248 

P 110 S 129 

Britannia Heights subdivision 55 

Brockville 55, A 178 C 224 D 248 

P 110 S 129 

Brockville Chemicals Limited 162 

Bronze Medallion house 39, 52 

Brush control 18, 84 

Brussels A 178 C 224 D 248 

P 110 S 129 

Buchanan, E. V., T.S 68 

Building materials industry, power and 

energy supplied 44 

Bundle conductors 78, 80, 83 

Burford 50, A 178 C 224 D 248 

P 110 S 129 
Burgessville A 178 C 224 D 248 

P 110 S 129 
Burk's Falls A 179 C 224 D 248 

P 110 S 129 

Burks Falls G.S 92 

Burlington 51, A 179 C 224 D 248 

P 110 S 129 

Burlington Steel Company Limited 162 

Burlington T.S 66 

Buttonville T.S 67 



CANDU, see Douglas Point Nuclear 

Power Station 
Cable, underground 68, 81 



268 



Index 



Cable-type dampers replaced 18 

Cache Bay 161 , A 216 C 224 D 248 

P 142 S 146 

Calabogie G.S 92 

Calcium chloride 85 

Caledonia 51, A 179 C 224 D 248 

P 110 S 129 

Camera, closed-circuit television 83 

Cameron Falls G.S 93, 136 

Campbellford 54, A 179 C 224 D 248 

P 110 S 129 

Campbellville A 179 C 224 D 248 

P 110 S 129 

Canada Starch Company, Limited 162 

Canadian Electrical Association 

Medal Award 89 

Canadian Electrical Code 57 

Canadian General Electric Company 

Limited 76 

Canadian Industries, Limited 162 

Canadian Johns-Manville Company 

Limited 162 

Canadian Labour Congress 88 

Canadian National Exhibition 57 

Canadian Niagara Power Company, 

Limited 92, \62 

Cannington A 179 C 224 D 248 

P 110 S 129 
Capacity, dependable peak — 

all systems v, 3, 6, 10, 93, 94 

denned .91 

increase 7, 10 

sources of purchased power 92, 93 

see also N.O.P. & S.O.S. 
Capacity of generating resources. . .59, 92, 93 

Capital, net — of the Commission 23 

see also N.O.P. & S.O.S. 

of municipal electrical utilities 170-219 

Capital construction program 60-2 

Capital expenditure, see Expenditure 
Capital investment, see Assets, fixed, of 
the Commission, M.E.U., and Rural 
electrical service 

Capreol 56, 161, A 216 C 224 D 248 

P 142 S 146 
Cardinal . . . .A 179 C 224 D 248 P 110 S 129 

Caribou Falls G.S 93, 136 

Carlaw Station 52 

Carleton Place A 179 C 224 D 248 

P 110 S 129 

Casselman A 179 C 224 D 248 

P 110 S 129 
Cayuga. . ...A 180 C 224 D 248 P 110 S 129 
Cement industry, power and energy 

supplied 44 

Central Region . 19, 45, 46, 52, 54, 67, 152, 154 

Chalk River 6, 55, A 180 C 224 D 248 

P 110 S 129 

Chapleau G.S 93 

Chapleau Twp A 216 C 224 D 248 

Chatham 49, 50, A 180 C 224 D 248 

P 110 S 129 

Chats Falls 12 

Chats Falls G.S 13,66, 92, 100 

Chatsworth A 180 C 224 D 248 

P 110 S 129 

Chemical control of wood growth 19 

Chemical industry, power and energy 

supplied 43, 44 

Chenaux G.S 92, 100 

Chesley A 180 C 224 D 248 P 110 S 129 



Chesterville A 180 C 224 D 248 

P 110 S 129 

Chippawa 52, A 181 C 224 D 248 

P 110 S 129 

Circuit-breakers 17, 66 

Classes of service described . 147, 148, 220, 221 

Clifford A 181 C 224 D 248 P 110 S 129 

Clinton A 181 C 224 D 248 P 110 S 129 

Cobalt . . . C 224 D 248 

Cobalt mining, power and energy 

supplied 43, 44 

Cobden 55, A 181 C 224 D 248 

P 110 S 129 

Cobourg 54, 63, A 181 C 224 D 248 

P 110 S 129 

Cochrane 161, A 216 C 224 D 248 

P 142 S 146 
Colborne. ...A 181 C 226 D 250 P 110 S 129 

Coldwater 54, A 181 C 226 D 250 

P 112 S 129 

Coldwater test station 78, 80 

Collingwood 54, A 181 C 226 D 250 

P 112 S 129 
Comber. ... .A 181 C 226 D 250 P 112 S 129 

Commercial service 96 

defined 148, 220 

municipal systems. . . .163, 164, 165, 166, 

223-65 

rural. . .46, 48, 149, 151-5 

Commission-owned facilities, see Local 
systems, and Rural electrical service 

Commissions, advisory 1 

Communications — power and energy 

supplied 44 

see also N.O.P. & S.O.S. — assets, fixed 
Competition for design of all-electric 

house 39 

Computer — analogue 80 

electronic 2 1 , 40 

Concrete pole protection 85 

Concreting practices 81 

Conductor-vibration recorder 81 

Coniston 55, A 216 C 226 D 250 

P 142 S 146 

Coniston G.S 93 

Consolidated Mosher Mines Limited 162 

Consolidated Sand & Gravel, Limited. . . .162 

Construction, aids to 80 

Construction Division 72, 89 

Consumption, energy — average per 

customer vi, 155, 164 

direct industrial customers 43 

municipal systems. . . 164, 165, 166, 244-65 

rural service 48, 155 

Cooking school 57 

Cookstown 54, A 182 C 226 D 250 

P 112 S 129 

Cooksville T.S 67 

Cooling, artificial, for lead cable sheath. . .81 

Corona 78, 80 

Corporations Act, The 157 

Cost, average, per kwh 221 

municipal systems 22, 164, 165, 166, 

244-65 

rural service 48, 155 

Cost-contract utilities. .. .21, 22, 25, 26, 27, 

32, 33, 41, 55 

Cost increases 21, 22, 26 

Cost of power 21, 22, 32, 33 

adjustments, annual 5, 22, 32, 33 

statements of, N.O.P 142-5 

S.O.S 108-27 



Index 



269 



Cost of providing service v, 4, 5, 21, 22 

N.O.P 26, 33 

R.P.D 32, 33 

S.O.S. .25 32 

Cottam .' ". '. '. . A 182 C 226 D 250 P 112 S 129 
Courtright . .A 182 C 226 D 250 P 112 S 129 

Cranes, mobile 85 

Creemore. ..A 182 C 226 D 250 P 112 S 129 

Crowland Twp 52 

Crystal Falls G.S 93 

Customers, direct industrial, . v, 4, 21, 24, 32, 

33, 40, 42, 43, 44 

power and energv supplied. . .43, 44, 95, 97, 

126, 144 
Customers, number of — 

direct industrial 43 

municipal 41, 170 

rural 45, 46, 47, 151-5 

served by municipal systems 163, 164, 

244-65 

ultimate 6, 41 

Cyanamid, power and energy 

supplied 43, 44 

Cyanamid of Canada Limited 162 



I) 



Dampers 18 

Dash wood. ..A 182 C 226 D 250 P 112 S 129 

Data processing, electronic 21, 88 

Debt, long-term — of the Commission. .23, 167 

see also N.O.P. & S.O.S.— liabilities 
of the municipal electrical utilities. . . . 167, 

170-219 

DeCew Falls G.S 92, 100 

Deep River A 182 C 226 D 250 

P 112 S 129 

Deer Horn Mines Limited 162 

Deficit, statement of 22, 33 

Delaware. . .A 183 C 226 D 250 P 112 S 129 

Delhi. . A 183 C 226 D 250 P 112 S 129 

Deliveries of power and energy in 

wholesale quantities 40, 41, 95 

Demand, see Requirements 

Demand recorders, digital 40 

Denison Mines Limited 162 

Density, watts, of water-heaters 85 

Dependable peak capacity, see Capacity, 

dependable peak 
Depreciation, accumulated — Commission . . 24 

see also N.O.P. & S.O.S. 

municipal 167, 170-219 

Deputy Provincial Treasurer 158, 159 

Deseronto 54, A 183 C 226 D 250 

P 112 S 129 

Design — aids to 80 

for nuclear power station 83 

Des Joachims G.S 60, 62, 63, 92, 100 

Detroit Edison Company 92 

Detweiler T.S 67, 69 

Development program 60-2 

Dielectric strength of ropes 83 

Diesel-electric generating facilities 93 

Dike— at Little Long G.S 72 

at Pumping-Generating Station 82 

Direct industrial customers, see 

Customers, direct industrial 
Distribution line, see Line 
District Forester 74 



Dobbin, Ross L., T.S 68 

Domestic service, see Residential service 
Dominion Engineering Company Limited . 75 
Dominion Tar & Chemical Company. . . . 162 

Don Fleet Jet 68 

Dorchester. .A 183 C 226 D 250 P 112 S 129 

Douglas Point Nuclear Power Station, .vi, 6, 

7, 60, 62, 63, 65, 67, 68, 81, 83, 100 

Drayton A 183 C 226 D 250 P 112 S 129 

Dresden A 183 C 226 D 250 P 112 S 129 

Drumbo A 183 C 226 D 250 P 112 S 129 

Dryden. .56, A 217 C 226 D 250 P 142 S 146 

Dryden T.S 77 

Dryers, electric clothes 50 

Dublin A 183 C 226 D 250 P 112 S 129 

Dundalk 54, A 183 C 226 D 250 

P 112 S 129 
Dundas 51, 63, A 184 C 226 D 250 

P 112 S 130 
Dunnville. . .A 184 C 226 D 250 P 112 S 130 

DuPont of Canada Limited 162 

Durham A 184 C 226 D 250 P 112 S 130 

Dutton A 184 C 226 D 250 P 112 S 130 



E. V. Buchanan T.S., see Buchanan, 
E. V., T.S. 

Ear Falls G.S 93 

East Central Region 45, 46, 54, 68, 89, 

153, 154 

Eastern Ontario Division 2, 100 

Eastern Region. . . 19, 46, 55, 68, 89, 153, 154 

Eastman, D 89 

Eastview, see Ottawa 

East York Twp A 184 C 226 D 250 

P 112 S 130 

Economies in construction 24 

Efficiencies, hydraulic and thermal 11 

Eganville. . .A 184 C 226 D 250 P 112 S 130 

Elastometers 82 

Eleanor Rapids 15 

Electric heating 38, 39, 49, 51-5 

Electrical industry vi 

Electrical maintenance 16 

Electrochemical industry, power and 

energy supplied 43, 44 

Electrometallurgical industry, power 

and energy supplied 43, 44 

Electronic data processing 21, 88 

Elk Lake Townsite C 226 D 250 

Elliott Chute G.S 93 

Elmira A 185 C 226 D 250 P 112 S 130 

Elmira T.S 66 

Elmvale A 185 C 226 D 250 P 112 S 130 

Elmwood . . .A 185 C 226 D 250 P 112 S 130 

Elora A 185 C 226 D 250 P 112 S 130 

Embro A 185 C 226 D 250 P 112 S 130 

Employee training 87, 88 

Employees Union, Ontario Hydro 88 

Employment statistics 6, 87 

Energy — 

consumption, see Consumption 

produced for commercial load v, 3, 6, 

10, 11,93, 94 
see also N.O.P. & S.O.S. 

purchased .v, 6, 10, 11, 92-4 

requirements, see Requirements 



Code letters A, C, D, with page references, represent each of the statements so designated, 
of Primary Power, and 5 Sinking Fund Equity. 



P represents Cost 



270 



Index 



Energy- — continued 

supplied — to Commission customers. . 6, 7, 
21, 25, 26, 40, 06 

primary, in wholesale quantities 95 

to direct industrial customers. .40, 43, 
44, 95, 97, 126, 144 

to interconnected systems 40, 44, 

95, 97 

to municipal systems. .40, 42, 95, 96, 

108-27, 142-5, 164 

to R.P.D 40, 46, 95, 97, 126, 144 

for use in Ontario 10 

secondary — for export. ... 25, 32, 33, 126 

in wholesale quantities. . .7, 15, 25, 26, 

40, 44, 95, 126, 144 

Engineering computations 21 

Englehart. 56, C 226 D 250 

English River 15 

Epoxy resins 80 

Equity in Ontario Hydro systems, 
see M.E.U. — equity 

Erieau A 185 C 226 D 250 P 112 S 130 

Erie Beach ..A 185 C 226 D 250 P 112 S 130 

Erin... A 185 C 226 D 250 P 112 S 130 

Escalation, cost-of-living 88 

Espanola 41,56, 161, A 217 C 226 D 250 

P 142 S 146 

Espanola T.S 56, 77 

Essa T.S 62, 67, 69 

Essex 63, A 185 C 226 D 250 

P 112 S 130 

Essex County 49 

Etobicoke Twp 52, 53, 67, A 186 C 226 

D 250 P 112 S 130 

Eugenia G.S 92 

Executive Council of the Province 

of Ontario 1 

Exeter A 186 C 228 D 252 P 112 S 130 

Exolon Company 162 

Expenditure — capital \i, 6, 61 

fixed assets vi, 23, 24 

municipal 166, 170-219 

nuclear research 24 

Export, 60-cvcle secondary energy. . . .25, 32, 

33, 126 

Extra-high-voltage test project 78, 80 

Extra-high-voltage transmission vi, 62, 80, 83 



Farm service. . . .46, 48, 96, 147, 149, 151-5 

Fatigue failure in cable sheath 81 

Fergus. A 186 C 228 D 252 P 112 S 130 

Financial features of the Commission 4 

Financial operations — of the Commission. .21 

of the municipal electrical utilities 164 

Financial position, summary of — 

all systems 23 

municipal electrical utilities 166 

Finch A 186 C 228 D 252 P 114 S 130 

Fires due to electrical causes 57 

First-aid instruction 90 

Fixed-rate utilities 41, 55 

Flat-rate water-heater service. . . .220, 222-65 
Flesherton . .A 186 C 228 D 252 P 114 S 130 

Fluorescent lighting 51, 54, 55, 56 

Fly ash 81 

Ion thill A 186 C 228 D 252 P 114 S 130 

Ford Motor Company of Canada, 

Limited 162 

Forebay level tests 14 



Forest A 187 C 228 D 252 P 114 S 130 

Forest Hill . A 187 C 228 D 252 P 114 S 130 

Forestry 19 

Fort William 5, 56, 62, 69, A 217 C 228 

D 252 P 142 S 146 

Fountain Falls G.S 93 

Frankford ...A 187 C 228 D 252 P 114 S 130 

Frankford G.S 92 

French River 2 

Frequency of accidents 89 

Frequency-changer 13, 66, 67 

Frequency standardization 24, 25, 87 

Fuel-electric generating facilities, see 

Thermal-electric generating facilities 
Funded debt. 34-7 

exchange discount and premium . . 105, 140 

see also N.O.P. & S.O.S. 
Fungi 83 



Galetta G.S 92 

Gait .A 187 C 228 D 252 P 114 S 130 

Gas competition vi 

Gatineau Power Company 92 

Gatineau River 18 

Generating stations 59, 61, 62, 92, 93 

see also individual listings 
" " N.O.P. & S.O.S.— assets 
George W. Rayner G.S., see Rayner, 

George W., G.S. 

Georgetown 52, A 187 C 228 D 252 

P 114 S 130 

Georgian Bay Division 2, 100, 102 

Georgian Bay Region. 19, 46, 54, 67, 152, 154 

Geraldton C 228 D 252 

Glass insulators 68 

Glencoe A 187 C 228 D 252 P 114 S 130 

Glen Lawrence Construction Company.. .162 

Glen Williams, see Georgetown 

Goderich ....A 187 C 228 D 252 P 114 S 130 

Gogama C 228 D 252 

Gold Medallion house 39, 52 

Gold mining industry, power and 

energy supplied 43, 44 

Government of Ontario, see Ontario, 

Province of 
Government services, power and energy 

supplied 44 

Graf, Jurij 89 

Grain elevators, power and energy 

supplied 44 

Grand Bend A 187 C 228 D 252 

P 114 S 130 

Grand Valley A 187 C 228 D 252 

P 114 S 130 

Grantham Twp 52 

Grant-in-aid, see Assistance, Provincial, 

for rural facilities 

Granton A 188 C 228 D 252 P 114 S 130 

Gravenhurst A 188 C 228 D 252 

P 114 S 130 
Great Lakes Power Corporation, Limited.. 93 
Grimsby. . . .A 188 C 228 D 252 P 114 S 130 

Guelph". 51, 63, A 188 C 228 D 252 

P 114 S 130 
Guide to the Report 7 



H 



Hagersville 51 



A 188 C 228 D 252 
P 114 S 130 



Index 



271 



Hagues Reach G.S 92 

Haileybury C 228 D 252 

Hamilton 51,66, 68, ,4 188 C 228 

I) 252 P 114S 130 

Hamilton-Gage T.S 66 

-Kenilworth T.S 66 

Hamlet service. ...46, 48, 96, 148, 149, 151-5 

Hanna Chute G.S 92 

Hanover 69, A 189 C 228 D 252 

P 114 S 130 

Hanover G.S 92 

Hanover T.S 67 

Harmon G.S vi, 6, 60, 62, 69, 72, 76 

Harriston A 189 C 228 D 252 

P 114 S 130 

Harrow A 189 C 228 D 252 P 114 S 130 

Hastings. . ..A 189 C 228 D 252 P 114 S 130 

Havelock 54, A 189 C 228 D 252 

P 114 S 130 

Hawkesbury 55, A 189 C 228 D 252 

P 114 S 130 

Hayes Steel Products Limited 162 

Hays Lake 16 

Health of employees 90 

Hearn, Richard L., G.S vi, 5, 7, 9, 13, 

60, 62, 63, 64, 67, 68, 84, 92, 100 

Hearst A 217 C 228 D 252 

Heating, electric. . 38, 39, 49, 51, 52, 53, 54, 55 

Heely Falls G.S. . 92 

Helicopter operations 18, 84 

Helium in balloon 84 

Hensall A 189 C 228 D 252 P 114 S 130 

Hepworth C 228 D 252 

Hespeler. ...A 189 C 228 D 252 P 114 S 130 

High Falls G.S 92 

Highgate. . . .A 189 C 228 D 252 P 114 S 130 

High-lift concrete placement 81 

High-voltage test laboratory 63 

Holden, Otto, G.S 92, 100 

Holstein ....A 190 C 228 D 252 P 114 S 131 

Hornepayne C 228 D 252 

Hornepayne G.S 93 

Hospitalization premiums 88 

Hound Chute G.S 93 

House heating 50, 220, 222-43 

Hudson Townsite C 228 D 252 

Humberstone Twp 52 

Huntsville.. .A 190 C 228 D 252 P 114 S 131 
Hydraulic disturbance at Aguasabon G.S. . 16 

Hydraulic efficiency 11 

Hydro-electric generating facilities. ... 11, 59, 

92, 93, 100, 136 
Hydro-Electric Power Commission of 
Ontario, The — 

established 1 

financial features 4 

legislation 1 , 156 

membership 1 

power supply 2,4 

systems 2 

Hydrogen in balloon 19, 84 

"Hydro Showtime" 56 

Hydrostatic level 62 



Ice, load-carrying capacity of 85 

Ice storms in 1959 and 1960 19 

Imperial Oil Limited 162 

Increase in rates to industrial customers, v, 21 



Indian Chute G.S 93 

Industrial customers, see Customers, 
direct industrial 

Industrial power service 96 

defined 148, 220-1 

municipal systems 163, 164, 165, 166, 

223-65 

rural. 46, ±8, 149, 150, 151-5 

Industrial relations 88, 89 

Ingersoll 50, A 190 C 228 D 252 

P 114 S 131 

I nspection 57 

Instruction in first aid 90 

Insulation, thermal 82, 83 

Insulator hardware 68, 80 

Insurance fund, Commission 24 

I nterchange — between operating 

systems. . . .2, 10, 27, 32, 33, 94, 126, 144 

with other utilities 13, 16, 43 

Interconnected systems 4, 40, 42, 44 

Interest costs v, vi, 21, 24, 25 

Interim rates v, 5, 21, 42, 109-25, 143 

International Ploughing Match 57 

International Union of Operating 

Engineers 88 

Inventories, reduction in vi 

Inventory data 21 

Iroquois 55, A 190 C 230 D 254 

P 114 S 131 



J 

J. Clark Keith G.S., see Keith, 
J. Clark, G.S. 

James Bay watershed vi, 6, 77 

Jarvis 51, A 190 C 230 D 254 

P 114 S 131 

Jellicoe Townsite C 230 D 254 

Jointing technique 83 

Joints in distribution cable 80 

Journeymen, training 87 



K 



Kagawong G.S 93 

Kakabeka Falls G.S 93 

Kam-Kotia Porcupine Mines, Limited. . .162 
Kapuskasing. .62, 63, 69, 70, 71, A 217 C 230 

D 254 P 142 S 146 

Kearns Townsite C 230 D 254 

Keith, J. Clark, G.S 92, 100 

Kemptville. .A 190 C 230 D 254 P 114 S 131 

Kenora 63 

Kincardine 6, 7, 63, 65, A 191 C 230 

D 254 P 114 S 131 

King Kirkland Townsite C 230 D 254 

Kingston ....A 191 C 230 D 254 P 114 S 131 
Kingsville. ..A 191 C 230 D 254 P 114 S 131 

Kipling G.S vi, 6, 60, 62, 69, 72, 76 

Kirkfield 54, A 191 C 230 D 254 

P 116 S 131 

Kirkland Lake 56, C 230 D 254 

Kitchener 51, A 191 C 230 D 254 

P 116 S 131 



Code letters A, C, D, with page references, represent each of the statement 
of Primary Power, and 5 Sinking Fund Equity. 



s so designated. P represents Cost 



272 



Index 



Labour Relations Board of Ontario 89 

Lakefield 54, A 191 C 230 D 254 

P 116 S 131 

Lakefield G.S 92 

Lakefront Area staff 89 

Lake Huron 7, 65, 72 

Lake Nipissing 2 

Lake Ontario 64 

Lake St. Joseph 15 

Lake Superior 16 

Lakeview G.S vi, 5, 60, 62, 63, 64, 67, 68, 

84, 100 
Lambeth. . ..A 191 C 230 D 254 P 116 S 131 

Lanark A 191 C 230 D 254 P 116 S 131 

Lancaster. . .A 191 C 230 D 254 P 116 S 131 
Lands and Forests, Department 

of, Ontario 74 

Larder Lake Twp... .161, A 217 C 230 D 254 

P 142 S 146 

Latchford 161, A 217 C 230 D 254 

P 142 S 146 

Lead alloy sheath material 81 

Lead cable 81 

Leamington A 192 C 230 D 254 

P 116 S 131 

Leaside 53 

see also Toronto 
Legislature of the Province of 

Ontario 41, 53, 156 

Liabilities, long-term, see Debt, long-term, 
and N.O.P. & S.O.S. 

Lieutenant-Governor in Council 1, 157, 

158, 159 

Lighting 38, 57 

Lightning 80 

Lindsay A 192 C 230 D 254 P 116 S 131 

Lindsay Explorations Limited 162 

Line — municipal distribution. . .49,50,51,52, 

53, 55 

rural distribution 6, 45, 46, 47, 151-4 

transmission 6, 14, 16, 18, 61, 80 

Linseed oil in concrete pole treatment. . . .85 
Listowel . . . .A 192 C 230 D 254 P 116 S 131 

Little Long G.S vi, 6, 60, 62, 63, 69, 70, 

76, 81, 136 

Little Long Rapids 90 

Little White River 72, 73 

Load 6, 9, 10,22,94 

direct industrial customers 43, 44 

interconnected systems 44 

municipal systems 42, 246-65 

peak— defined 42, 91 

of Toronto Hydro-Electric System.. . .52 

rural 46 

see also N.O.P. & S.O.S. 
Load characteristics of electric 

water-heaters 84 

Local distribution systems. . . .4, 21, 40, 41, 
42, 95, 96, 163,' 164, 165, 222-43, 246-65 
see also N.O.P. & S.O.S.— assets 

London 49, 68, A 192 C 230 D 254 

P 116 S 131 

London-Nelson T.S 66 

London Twp A 192 C 230 D 254 

P 116 S 131 

Long Branch A 192 C 230 D 254 

P 116 S 131 

Long-service records of staff 86 

L'Orignal 55, A 193 C 230 D 254 

P 116 S 131 



Lower Sturgeon G.S 93 

Low-lift concrete placement 81 

Lucan A 193 C 230 D 254 P 116 S 131 

Lucknow. ...A 193 C 230 D 254 P 116 S 131 
Lynden A 193 C 230 D 254 P 116 S 131 



M 



Maclaren -Quebec Power Company 92 

Madawaska River 62 

Madoc A 193 C 230 D 254 P 116 S 131 

Magnetawan A 193 C 230 D 254 

P 116 S 131 

Maintenance — aids to 83 

of the systems 16 

Management staff, training 87, 88 

Manby, A. W., T.S 67, 68 

Manila ropes 83 

Manitoba Hydro-Electric Board. . . 15, 16, 93 

Manitou Falls G.S 93, 136 

Manitoulin Island 77 

Manitouwadge 16 

Manordale D.S 68 

Manpower planning and development. . . . 87 

Manufacturers of electric equipment 38 

Manufacturing industry, power and 

energy supplied 43, 44 

Markdale ...A 193 C 230 D 254 P 116 S 131 
Markham ...A 193 C 230 D 254 P 116 S 131 
Marmora 54, A 193 C 230 D 254 

P 116 S 131 

Marshall, J. K 89 

Martindale, R. H., T.S 62 

Martintown A 194 C 230 D 254 

P 116 S 131 
Massey 55, 161, A 217 C 230 D 254 

P 142 S 146 

Matabitchuan G.S. 93 

Matachewan Twp C 230 D 254 

Matheson C 230 D 254 

Mattagami River vi, 6, 12, 60, 61, 62, 

69, 70, 72, 77 

Mattawa C 230 D 254 

Mattawa River 2 

Matured sinking fund, see Sinking fund 
Maxville. ...A 194 C 230 D 254 P 116 S 131 
McGarry 161, A 217 C 232 D 256 

P 142 S 146 

McKim Twp 56 

McVittieG.S 93 

Meaford 54, A 194 C 232 D 256 

P 116 S 131 

Mechanical maintenance 17 

Medallion standards 39, 52, 58 

Medical premiums 88 

Medical services 90 

"Men of Power" film 57 

Mercury-vapour lighting 51, 55 

Merlin A 194 C 232 D 256 P 116 S 131 

Merrickville A 194 C 232 D 256 

P 116 S 131 

Merrickville G.S 92 

Merritton 52, A 194 C 232 D 256 

P 116 S 131 
Metropolitan Toronto, see Toronto 

Meyersburg G.S 92 

Midland . . . .A 195 C 232 D 256 P 116 S 131 
Mildmay. . . .A 195 C 232 D 256 P 116 S 131 
Millbrook. ..A 195 C 232 D 256 P 116 S 131 
Milling industry, power and energy 

supplied 44 

Milton A 195 C 232 D 256 P 116 S 131 



Index 



273 



Milverton. . .A 195 C 232 D 256 P 116 S 131 
Mimico A 195 C 232 D 256 P 116 S 131 

Mining industry, power and energy 

supplied 43, 44 

Minnesota-Ontario Paper Company 15 

Minimum energy charge for summer 

cottages 21 

Missinaibi River 62 

Mission River 69 

Mississagi Provincial Forest 72 

Mississagi River vi, 5, 60, 62, 72 

Mitchell. ...A 195 C 232 D 256 P 116 S 131 

Montreal River 12, 62 

Moorefield . .A 195 C 232 D 256 P 116 S 131 
Morrisburg. .A 195 C 232 D 256 P 116 S 131 

Moses, Robert, Niagara G.S 66 

Mount Brvdges A 196 C 232 D 256 

P 118 S 132 

Mount Forest A 196 C 232 D 256 

P 118 S 132 

Mount Hope Jet 68 

Municipal accountants of the 

Commission 42 

Municipal Act of Ontario, The 159 

Municipal Affairs, Department of, 

Ontario 168 

Municipal distribution systems.. .49ff, 244-65 

Municipal electrical service 163ff 

Municipal electrical utilities. . . v, vi, 2, 4, 5, 6, 
8, 21, 22, 24, 25, 38, 40, 41, 42, 49ff, 164ff 

accounts 42, 170-219 

added in 1960 41, 56 

assets 166, 170-219 

assets, fixed 167, 170-219 

commercial service. ... 163, 164, 165, 166, 

220, 223-65 

cost, average, per kwh 164, 165, 166, 

244-65 

cost-contract 21, 22, 25, 26, 27, 32, 33, 

41, 55 

cost of power 32,33, 108-27, 142-5 

customers served 6, 41, 163, 164, 

170-219, 244-65 

debt 167, 170-219 

depreciation 167, 170-219 

energy — consumption 164, 165, 166, 

244-65 
supplied. . .40, 42, 95, 96, 108-27, 142-5, 

164 
equity in Ontario Hydro systems. . . . 167, 

170-219 

financial operations 164, 166 

financial statements 170-219 

fixed-rate 41, 55 

industrial power service 163, 164, 165, 

166, 220, 223-65 

line 49, 50, 51, 52, 53, 55 

loads 42, 246-65 

power supplied. . .42, 108-27, 142-5, 246-65 

rates— interim v, 5, 21,42, 109-25, 143 

retail vi, 5, 54, 56, 163, 168, 220-43 

residential service 163, 164, 165, 166, 

220, 222-64 

revenue 163, 164, 166, 170-219 

Muskeg 78 

N 

Xapanee. . . .A 196 C 232 D 256 P 118 S 132 
National Harbours Board 162 



National Safety Council Award of Merit ... 89 
National Safety Council President's Medal. 89 
National Union of Public Service 

Employees (CLC) 88 

Natural gas competition vi 

Neale Jet 68 

Neelon Steel Limited 162 

Neelon Twp 56 

Neoprene rubber 83 

Neustadt . . .A 196 C 232 D 256 P 118 S 132 
Newboro. ...A 196 C 232 D 256 P 118 S 132 
Newburgh. ..A 196 C 232 D 256 P 118 S 132 
Newbury. . . . A 197 C 232 D 256 P 118 S 132 

Newcastle 52, 54, A 197 C 232 D 256 

P 118 S 132 

New Hamburg A 197 C 232 D 256 

P 118 S 132 

New Liskeard 56, C 232 D 256 

Newmarket 53, A 197 C 232 D 256 

P 118 S 132 

New Toronto A 197 C 232 D 256 

P 118 S 132 

Niagara A 197 C 232 D 256 P 118 S 132 

Niagara area 82 

Niagara Division 2, 100 

Niagara Falls.... 13, 17, 52, 66, A 197 C 232 

D 256 P 118 S 132 

Niagara Mohawk Power Corporation . 13, 66, 

92, 162 

Niagara Parks T.S 66 

Niagara Region 46, 52, 66, 89, 152, 154 

Niagara River 12, 92, 100 

Niagara Twp 52 

Nipigon Twp A 218 C 232 D 256 

P 142 S 146 

Nipissing G.S 93 

Non-metals mining industry, power 

and energy supplied 43, 44 

North Bay 161, A 218 C 232 D 256 

P 142 S 146 
Northeastern Division. . .v, 2, 10, 12, 15, 21, 

41, 62, 136 

Northeastern Expressway 51 

Northeastern Region 19, 46, 55, 154, 160 

Northern Ontario Properties. . . .v, 2, 15, 20, 
22, 26, 41, 46, 59, 60, 69, 160, 161, 168 

advances from the Province 31, 37 

assets 30, 136-9 

assets, fixed 30, 136-9 

assistance, Provincial 31 

balance sheet 30-1 

capacity, dependable peak 10, 14, 15, 

93, 94 

capital 31 

cost of power 26, 27, 33, 142-5 

average per lew 27 

cost of providing service 26, 33 

defined 2 

depreciation provision 26, 30, 33, 140 

energy — produced for commercial 

load 10, 15, 16, 93,94 

purchased 93, 94 

secondary 15, 16, 26 

supplied in wholesale quantities. . 15, 26, 

95, 142-5 

transferred 94, 126, 144 

frequency standardization 27, 140 

funded debt 35-7 

liabilities 26, 31 

load 10, 11, 14, 15, 16, 95 



Code letters A, C, D, with page references, represent each of the statements so designated, 
of Primary Power, and 5 Sinking Fund Equity. 



P represents Cost 



274 



Index 



Northern Ontario Properties — continued 

operation 15 

operations, financial 26 

statement of 33 

power — produced for commercial load . . 10, 
14, 15, 16, 93, 94 

purchased 14, 15,93,94 

supplied in wholesale quantities 26, 

142-5 

transferred 27, 32, 33, 94, 126, 144 

progress on power developments 69 

refunds to municipalities 33, 143-5 

requirements — primary energy 10, 16 

primary peak 10, 14, 15, 16, 95 

reserves — statements of 140, 141 

withdrawals from v, 26, 27, 33 

resources 10, 14, 15, 93, 95 

revenue 2d, 33 

rural, see Rural electrical service 

sinking fund equity 146 

transformer stations 77 

transmission lines 63, 77 

Northwestern Division. . . . v, 2, 11, 12, 15, 16, 

21, 136 

Northwestern Region 19, 56, 154, 160 

North York Twp 52, 67, A 197 C 232 

D 256 P 118 S 132 

Norton Company 162 

Norwich . . . .A 197 C 232 D 256 P 118 S 132 

Norwood 54, A 198 C 232 D 256 

P 118 S 132 

Nuclear-electric facilities 59 

Nuclear Power Demonstration, .vi, 5, 7, 60, 

62, 63, 65 

Nuclear power station design 83 

Nuclear research provision. . .24, 107, 109-27, 

141, 142-5 



Oakville-Trafalgar 41, 53, A 198 C 232 

D 256 P 118 S 132 

Office buildings 63 

Ogoki Diversion 100 

Oil circuit-breakers 66, 67 

Oil Springs. .A 198 C 232 D 256 P 118 S 132 

Omemee A 198 C 232 D 256 P 118 S 132 

Ontario, Province of 2, 5, 8, 49, 156, 159 

account 30 

Ontario Association of Architects 39 

Ontario Hydro Employees Union 88 

Ontario-Minnesota Pulp & Paper 

Company 93 

Ontario Municipal Board 52 

Ontario Power G.S 92, 100 

Operating Engineers, International 

Union of 88 

Operating results 21 

by systems 25 

Operations — aids to 83 

research 11 

statements of, Commission 32, 33 

municipal 170-219 

Orangeville 54, 67, 69, A 198 C 232 

D 256 P 118 S 132 

Order in Council 161-2 

Orenda Engines Limited 162 

Orillia A 198 C 232 D 256 P 118 S 132 

Orono 54, A 199 C 232 D 256 

P 118 S 132 



Oshawa 52, 54, A 199 C 232 D 256 

P 118 S 132 

Oshawa R.O.A 45 

Ottawa 55, 68, A 199 C 234 D 258 

P 118 S 132 

Ottawa T.S 68 

Ottawa-Hawthorne T.S 68 

-National Research T.S 68 

-Overbrook T.S 68 

-Riverdale T.S 68 

-Slater T.S 68 

Ottawa River. . .6, 12, 18, 62, 63, 65, 92, 100 

Ottawa Valley Power Company 92 

Otter Rapids 5, 81 

Otter Rapids G.S vi, 60, 62, 69, 76, 136 

Otterville ...A 199 C 234 D 258 P 118 S 132 
Otto Holden G.S., see Holden, Otto, G.S. 

Output, net — of all resources 10, 11, 94 

of Commission stations 11, 92-3, 94 

of sources of purchased power. 11, 92, 93, 94 

Owen Sound A 199 C 234 D 258 

P 118 S 132 



Packard T.S 66 

Paisley 54, A 199 C 234 D 258 

P 118 S 132 
Palmerston. .A 199 C 234 D 258 P 118 S 132 

Paper industry v, 21 

power and energy supplied 44 

Parallel operation with other 

utilities 13, 16 

Paris A 199 C 234 D 258 P 118 S 132 

Parkhill A 199 C 234 D 258 P 118 S 132 

Parrv Sound 54, A 200 C 234 D 258 

P 118 S 132 

PauganG.S 18 

Peak capacity, see Capacity, 

dependable peak 
Peak load, see Load 
Peak requirements, see Requirements 
Pembroke Electric Light Company 

Limited 162 

Penetanguishene A 200 C 234 D 258 

P 118 S 132 

Permits, inspection 57 

Perth A 200 C 234 D 258 P 118 S 132 

Peterborough 55, A 200 C 234 D 258 

P 118 S 132 

Petrolia A 200 C 234 D 258 P 118 S 132 

Photogrammetric surveys 62 

Pickering 54, A 200 C 234 D 258 

P 120 S 132 

Pickering Twp 67 

Pickle Lake Landing Townsite. . C 234 D 258 

Picton A 201 C 234 D 258 P 120 S 132 

Piezometer measurement 82 

Pinard T.S 62, 77 

Pine Portage G.S 93, 136 

Pipeline pumping services 44 

Plastics 80 

Plattsville 50, A 201 C 234 D 258 

P 120 S 132 

Ploughing Match, International 57 

Point Edward A 201 C 234 D 258 

P 120 S 132 
Pole replacement 18 



Polyethylene — pipes 81 

sheath-type cable 68 



Index 



275 



Port Elgin 7, 63, 65, 

Port Hope 54, 



Pore-water pressures 82 

Port Arthur 56, A 218 C 234 D 258 

P 142 S 146 
Port Burwell A 201 C 234 D 258 

P 120 S 132 

Port Carling A 201 C 234 D 258 

Port Colborne A 201 C 234 D 258 

P 120 S 132 
Port Credit 78, A 201 C 234 D 258 

P 120 S 132 
Port Dalhousie 52, A 201 C 234 D 258 

P 120 S 132 
Port Dover 50, A 201 C 234 D 258 

P 120 S 132 

201 C 234 D 258 
P 120 S 132 

202 C 234 D 258 
P 120 S 133 

Portland cement 82 

Port McNicoll A 202 C 234 D 258 

P 120 S 133 
Port Perry ..A 202 C 234 D 258 P 120 S 133 

Port Rowan 51, A 202 C 234 D 258 

P 120 S 133 

Port Stanley A 202 C 234 D 258 

P 120 S 133 

Powassan C 234 D 258 

Power — 

produced for commercial load. . . . 3, 4, 10, 

92, 93 
see also N.O.P. & S.O.S. 

purchased 3,4, 12, 14, 15, 92-5 

requirements, see Requirements 

resources 3, 10, 12, 14, 16 

supply 2, 40 

to direct industrial customers \Z,44, 

126, 144 

to municipal systems 42, 108-27, 

142-5, 246-65 

to R.P.D 46, 126, 144, 147 

Power Authority of the State of 

New York 66, 92 

Power Commission Act, The. . .1, 4, 57, 168 

Amendment 156ff 

Power development program 60, 61 

Power-line carrier 80 

Precipitation, relation to corona loss 80 

Prepaid sinking fund, see Sinking fund 
Prescott . . . A 202 C 234 D 258 P 120 S 133 

Preston A 203 C 234 D 258 P 120 S 133 

Priceville. . . . A 203 C 234 D 258 P 120 S 133 

Princeton 50, A 203 C 234 D 258 

P 120 S 133 

Progress on power developments 63, 69 

Pronto Uranium Mines Limited 162 

Protective devices 80 

Province of Ontario, see Ontario, 

Province of 
Provincial — advances, see Advances 
from Province of Ontario 
grants, see Assistance, Provincial, 
for rural facilities 

Provincial Legislature 1, 53 

Public relations 57 

Public Utilities Act, The 4 

Pulp and paper industry v, 21 

power and energy supplied 44 

Pumped-storage sites 60 

Purchased energy and power, see Energy, 
and Power 



Quarrying industry, power and 

energy supplied 44 

Quarter Century Club 86 

Quebec Hydro-Electric Commission . . .92, 93 
Queenston.. A 203 C 234 D 258 P 120 S 133 
Queenston-Chippawa Development, see 

Beck, Sir Adam, -Niagara G.S. No. 1 



R. H. Martindale T.S., see 
Martindale, R. H., T.S. 

Radio interference 78, 80 

Ragged Rapids G.S 92 

Rainy River. A 218 C 234 D 258 

Ranney Falls G.S 92 

Rate of growth, long-term, all systems. . . v, 9 

Rates vi, 5, 21 

interim v, 5, 21 , 42, 109-25, 143 

municipal retail. . vi, 5, 56, 163, 168, 220-43 

rural 148fr 

Rat Rapids G.S 93 

Rayner, George W., G.S 72, 73, 76, 77, 

93, 136 

Reactive power in Toronto area 67 

Rebates to cost-contract municipalities. . .22, 
32, 33, 109-27, 143-5 

Reburn, J. M 89 

Red Lake Twp C 234 D 258 

Red Rock. . .A 218 C 234 D 258 P 142 S 146 

Red Rock Falls G.S vi,5,7,9, 15, 60,62, 

69, 72, 73, 93, 136 

construction procedure 74 

electrical equipment 76 

general description 73 

headworks 73 

main station equipment 75 

superstructure 74 

Reforestation 19 

Regions, reports from 49ff 

Regulations made under The Power 

Commission Act 57 

Renfrew . . . . A 203 C 234 D 258 P 120 S 133 

Requirements — primary energy 10 

primary power v, 6,9, 10 

thermal-electric energy 11 

see also N.O.P. & S.O.S. 
Research laboratories of the 

Commission 63, 79, 85 

Reserve generating capacity 21 

Reserves 24 

provision 5, 22 

statements of, N.O.P 140, 141 

S.O.S 106, 107 

Reserves of power v 

Residential service 96 

defined 148, 220 

municipal systems 163, 164, 165, 166, 

222-64 

rural 46, 48, 149, 151-5 

Resins, epoxy 80 

Resources v, 3, 6, 10, 93, 94 

see also Capacity, dependable peak 
" " N.O.P. & S.O.S. 

Retail service in municipalities 4, 163 

Retirement of older hydraulic stations .... 25 



Code letters A, C, D, with page references, represent each of the statements so designated, 
of Primary Power, and 5 Sinking Fund Equity. 



P represents Cost 



276 



Index 



Revenue — of the Commission, . v, 6, 7, 11, 21, 

25 
see also N.O.P. & S.O.S., and 
Rural electrical service 
of municipal electrical utilities. . . . 163, 164, 

166, 170-219 

Rewinding generators 17 

Richard L. Hearn G.S. , see Hearn, 

Richard L., G.S. 
Richmond.. .A 203 C 236 D 260 P 120 S 133 

Richmond Hill 53, A 203 C 236 D 260 

P 120 S 133 

Rich view T.S 67 

Ridgetown . .A 203 C 236 D 260 P 120 S 133 
Ripley. . .54, A 203 C 236 D 260 P 120 S 133 

Ritchie, R. E 89 

Riverside 50, A 204 C 236 D 260 

P 120 S 133 

Roadeo contest, participation in 89 

Robert Moses Niagara G.S., see 

Moses, Robert, Niagara G.S. 
Robert H. Saunders-St. Lawrence G.S., see 

Saunders, Robert H., -St. Lawrence G.S. 
Rockcliffe Park, see Ottawa 
Rockland . . .A 204 C 236 D 260 P 120 S 133 
Rockwood.. .A 204 C 236 D 260 P 120 S 133 

Rocky Island Lake 73 

Rodney A 204 C 2 36 D 260 P 120 S 133 

Ropes 83 

Ross L. Dobbin T.S., see Dobbin, 
Ross L., T.S. 

Rosseau A 204 C 2 36 D 260 P 120 S 133 

Rural electrical service. . vii, 4, 21, 24, 40, 45ff 

assets, fixed 24, 28, 30, 49, 102, 138 

assistance, Provincial 5, 23, 29, 31, 49 

classes of service 46, 147-8, 149, 151-5 

consumption, average, per customer. . . .48 

cost, average, per kwh 48 

cost of providing service 32, 33 

customers 21 

number of vii, 45, 46, 47, 151-5 

farm 46, 151-5 

summer 48, 151-5 

transferred to municipal electrical 

utilities 45, 52 

energy — consumption 96, 155 

supplied . 46, 95, 97 

expenditure on facilities 23, 61 

line, miles of primary, .vii, 45, 46, 47, 151-4 

load growth 46 

operating areas 40, 41, 97, 150-4 

map facing page 148 

power supplied 46, 126, 144, 147 

rates 5,21,48, 148ff 

revenue 32, 33, 48 

Rural Hydro-Electric Distribution Act, 

The 5,49 

Rural Power District 2, 22, 45, 160 

see also Rural electrical service 

Ruse, F 89 

Russell A 204 C 236 D 260 P 120 S 133 



Safe practices 85 

St. Catharines 52, A 205 C 236 D 260 

P 120 S 133 
St. Clair Beach A 205 C 236 D 260 

P 120 S 133 
St. George . .A 205 C 236 D 260 P 120 S 133 



St. Jacobs. . .A 205 C 236 D 260 P 120 S 133 

St. Lawrence Power Project 84, 100 

St. Lawrence River 12, 92, 100 

St. Mary's 50, A 205 C 236 D 260 

P 120 S 133 
St. Thomas A 205 C 236 D 260 

P 122 S 133 
Sales of energy, see Energy — supplied 

Sales program 38, 40, 52, 84 

Sales training 88 

Sandwich East Twp...50, A 205 C 236 D 260 

P 122 S 133 
Sandwich West Twp. .50, A 205 C 236 D 260 

P 122 S 133 

Sandy Falls G.S 93 

Sarnia 14, A 205 C 236 D 260 

P 122 S 133 

Saskatchewan Power Corporation 16 

Saskatoon 16 

Saunders, Robert H.,-St. Lawrence G.S. . .76, 

92 
Scale deposit on water-heater elements. . . .85 

Scarborough Twp 52, 53,67 , A 206 C 236 

D 260 P 122 S 133 

Scarborough T.S 67 

Schreiber Twp A 218 C 236 D 260 

P 142 S 146 
Schumacher, see Timmins 
Seaforth .50, A 206 C 236 D 260 P 122 S 133 

Seaforth T.S 66 

Secondary energy 7, 10, 13, 15, 16, 25, 26, 

32, 33, 40, 44, 95, 126, 144 

Service buildings 63 

Service buildings and equipment, see 
N.O.P. & S.O.S.— assets, fixed 

Services to customers 57 

Severity index of accidents 89 

Severn River 12 

Seymour G.S 92 

Shear strains 81 

Shear strengths of soils 82 

Shelburne 54, A 206 C 236 D 260 

P 122 S 133 

Shrinkage, thermal, in concrete 82 

Sick leave plan 90 

Sidney G.S 92 

Sikorsky S55 helicopter 18 

Silicones 85 

Sills Island G.S 92 

Silver Falls G.S 93,136 

Silver-Miller Mines Limited 162 

Silver mining industry, power and 

energy supplied 43, 44 

Simcoe A 206 C 236 D 260 P 122 S 133 

Sinking fund — of the Commission . 21, 23, 25, 

26, 157 
see also N.O.P. & S.O.S. 
equity of municipal electrical 

utilities 167, 170-219 

Sioux Lookout A 219 C 236 D 260 

Sir Adam Beck-Niagara G.S., see 
Beck, Sir Adam, -Niagara G.S. 

Sky-wire stringing 18 

Slump, in concrete 81 

Smith's Falls A 206 C 236 D 260 

P 122 S 133 
Smithville. . .A 206 C 236 D 260 P 122 S 133 

Smoky Falls 70, 72 

Soil mechanics 82 

Soil testing 82 

Source of funds 24 



Index 



277 



Southampton A 207 C 236 D 260 

P 122 S 133 

Southern Ontario System. . .v, 2, 10, 12, 13, 

20, 21, 22, 25, 27, 41, 45, 59, 63, 65, 66, 

68, 160, 168 

advances from the Province 29, 36 

assets 28, 100-03 

assets, fixed 28, 100-03 

assistance, Provincial 29 

balance sheet 28-9 

capacity, dependable peak. . .10, 12, 92, 94 

capital 29 

cost of power 25, 26, 32, 108-27 

average per kw 25 

cost of providing service 25, 32 

defined 2 

depreciation provision 25, 28, 32, 104 

energy — produced for commercial 

load 10, 13,92, 94 

purchased 92,94 

secondary 13, 25 

supplied in wholesale quantities. .25, 95, 

108-26 

transferred 94, 126, 144 

frequency standardization 25, 105 

funded debt 34-7 

liabilities 25, 29 

load... 10, 12, 94 

operation 13 

operations, financial 25 

statement of 32 

power — export 13 

output at Sir Adam Beck-Niagara 

stations 14 

produced for commercial load . ... 10, 12, 

92, 94 

purchased 12,92,95 

supplied in wholesale quantities. ... 25, 

108-26 

transferred 27, 32, 33, 94, 126, 144 

progress on power developments 63 

refund to municipalities 32, 109-27 

requirements — primary energy 10 

primary peak 10, 12, 13, 95 

reserves — provision 25 

statements of 106, 107 

resources 10, 12, 92, 94 

revenue 25, 32 

rural, see Rural electrical service 

sinking fund equity : . . 128-35 

transformer stations 66 

transmission lines 63, 68 

South Falls G.S 92 

South Gloucester D.S 68 

South Porcupine Townsite C 236 D 260 

Spraying for brush control 18, 84 

Springfield . .A 207 C 236 D 260 P 122 S 133 
Spruce Falls Power and Paper Company 

Railroad 71 

Staff total, see Employment statistics 

Stamford Twp 52, A 207 C 236 D 260 

P 122 S 133 

Standard specifications 79 

Statutes of Ontario, Revised, 1960 1 

Stayner A 207 C 236 D 260 P 122 S 133 

Steel industry, power and energy 

supplied 43, 44 

Stereoplotter 62 

Stewartville G.S 92, 100 

Stinson G.S 93 



Stirling A 207 C 236 1) 260 P 122 S 133 

Stoney Creek A 207 C 236 J) 260 

V 122 S 133 

Storage conditions 12, 13 

Stouffville. ..A 207 C 236 D 260 P 122 S 133 
Stratford 51, A 207 C 236 D 260 

P 122 S 133 

Stratford T.S 66 

Strathroy . . A 207 C 236 D 260 P 122 S 133 

Stream-flows 11, 12 

Street lighting 51, 54, 55, 96, 160, 

163, 164, 165, 166 
Streetsville. .A 208 C 236 D 260 P 122 S 134 
Sturgeon Falls A 219 C 236 D 260 

P 142 S 146 

Sturgeon River 12 

Sudbury 45, 55, 56, 62, 77, 80, A 219 

C 236 D 260 P 142 S 146 

Sudbury District 72 

Summer service 21, 46, 48, 96, 148, 149, 

151-5 
Sun-Canadian Pipe Line Company 

Limited 162 

Sunderland 54, A 208 C 238 D 262 

P 122 S 134 
Sundridge. . .A 208 C 238 D 262 P 122 S 134 

Supervisory training 87 

Survey — appliance saturation 39 

residential loads 40 

Survey work 62 

Sutton A 208 C 238 D 262 P 122 S 134 

Swansea . . . A 208 C 238 D 262 P 122 S 134 
Swastika, see Kirkland Lake 

Switchgear, extra-high-voltage 80 

Synthetic-fibre ropes 83 

Systems 2 



Tara A 208 C 238 D 262 P 122 S 134 

Tavistock. . .A 209 C 238 D 262 P 122 S 134 

Taxation v, 21 

Tecumseh ...A 209 C 238 D 262 P 122 S 134 
Teeswater. . .A 209 C 238 D 262 P 122 S 134 

Telemetering 80 

Television camera, closed-circuit 83 

Terrace Bay 16, 56, A 219 C 238 D 262 

P 142 S 146 

Test position for circuit-breakers 17 

Thamesford A 209 C 238 D 262 

P 122 S 134 
Thamesville A 209 C 238 D 262 

P 122 S 134 
Thedford. ...A 209 C 238 D 262 P 122 S 134 

Thermal efficiency 11 

Thermal-electric generating facilities, . vi, 11, 
59, 82, 92, 100, 136 

Thermal insulation 82 

Thessalon bl,n,\b\,A 219 C 238 

D 262 P 142 S 146 

Thiokol filler for sealing cable ducts 83 

Thistletown, see Etobicoke Twp. 
Thornburv. .A 209 C 238 D 262 P 122 S 134 
Thorndale. . . A 209 C 238 D 262 P 122 S 134 

Thornloe C 238 D 262 

Thornton . . .A 209 C 238 D 262 P 122 S 134 
Thorold 52, A 210 C 238 D 262 

P 122 S 134 
Thunder Bay G.S vi, 5, 60, 62, 69, 77 



Code letters /I, C, D, with page references, represent each of the statements so designated, 
of Primary Power, and 5 Sinking Fund Equity. 



P represents Cost 



278 



Index 



Thunder Bay System v, 27, 145 

Tilbury A '210 C 238 D 262 P 122 S 134 

Tillsonburg 50, A 210 C 238 D 262 

P 124 S 134 
Time purchase plan for electric 

water-heaters 40 

Timmins C 238 D 262 

Todd, E. C 89 

Tornado in June 14 

Toronto. .4,5, 13,40,52,53,62,63,64,68,81 
A 210 C 238 D 262 P 124 S 134 

Toronto-Bathurst T.S 67 

-Esplanade T.S 67, 68 

-Fairbank T.S 67 

-Leaside T.S 103, 106 

-Main T.S 67 

-Runnymede T.S 67 

-Sheppard T.S 67 

-Strachan T.S 67 

-Teraulay T.S 67 

-Wiltshire T.S 67 

Toronto Power G.S .17, 92, 100 

Toronto Region, see Central Region 

Toronto Twp 52, A 210 C 238 D 262 

P 124 S 134 

Torsion-type dampers installed 18 

Tottenham 54, A 210 C 238 D 262 

P 124 S 134 

Trafalgar Twp. 41 , 53, C 238 P 124 

see also Oakville-Trafalgar 

Training, technical 87 

Transfer of power and energy. .27, 32, 33, 94, 

126, 144 

Transformer stations 23, 61, 66, 77 

see also individual listings 
" " N.O.P. & S.O.S.— assets, fixed 

Transformers, on-site repairs 17 

Transmission line 18, 23, 61, 62, 68, 77 

extra-high-voltage vi, 62, 80, 83 

total mileage 6, 63 

see also N.O.P. & S.O.S.— assets, fixed 

Transmission losses 11 

Transportation services, power and 

energy supplied 44 

Treasurer of Ontario 159 

Tree crusher 71 

Tree pruning and removal 19 

Trenton 54, A 211 C 238 D 262 

P 124 S 134 

Trethewey Falls G.S 92 

Triaxial testing of soils 82 

Tunnel repairs at Toronto Power G.S 17 

Tweed A 211 C 238 D 262 P 124 S 134 



U 



Ultimate customers served by the 

Commission and municipal electrical 

utilities 41 

Underground cable, see Cable 

Underground facilities 49, 51, 52, 68, 80 

Unemployment, effect of iv 

Univac 1 1 compu ter 11 

Upper Notch G.S 93 

Uranium mining industry, power and 

energy supplied 43, 44 

Urethane thermal insulation 83 

Uxbridge. . . A 211 C 238 D 262 P 124 S 134 



Vankleek Hill A 211 C 238 D 262 

P 124 S 134 
Vibration dampers for transmission line. . . .83 

Vibration recorder for conductors 81 

Victoria Harbour A 211 C 238 D 262 

P 124 S 134 
Vinyl protective coating 83 



W 



Walkerton. .A 211 C 238 D 262 P 124 S 134 
Wallaceburg A 211 C 238 D 262 

P 124 S 134 
Wardsville. .A 211 C 238 D 262 P 124 S 134 
Warkworth A 212 C 238 D 262 

P 124 S 134 
Wasaga Beach A 212 C 238 D 262 

P 124 S 134 
Waterdown A 212 C 238 D 262 

P 124 S 134 
Waterford. . .A 212 C 238 D 262 P 124 S 134 
Water-heating, electric. .40, 49, 50, 84, 220-65 

rental plan 46, 55, 84 

sales 55, 56 

Waterloo 51, A 212 C 238 D 262 

P 124 S 134 
Watford . . . A 212 C 238 D 262 P 124 S 134 
Waubaushene A 213 C 238 D 262 

P 124 S 134 

Wawaitin G.S 93 

Webbwood 55, 161, A 219 C 238 

D 262 P 142 S 146 
Welland 52, A 213 C 240 D 264 

P 124 S 134 
Wellesley . . .A 213 C 240 D 264 P 124 S 134 
Wellington. A 213 C 240 D 264 P 124 S 134 

Wenebegon River 72 

West Central Region. 19, 46, 50, 66, 151, 154 

Western Region 46, 49, 50, 66, 151, 154 

West Ferris Twp 56, 161, A 219 C 240 

D 264 P 142 S 146 
West Lome A 213 C 240 D 264 

P 124 S 134 

Weston A 213 C 240 D 264 P 124 S 134 

Westport. ...A 213 C 240 D 264 P 124 S 134 
Wheatley . . A 213 C 240 D 264 P 124 S 134 
Whitby 54, A 214 C 240 D 264 

P 124 S 134 

Whitedog Falls G.S 93,136 

White River C 240 D 264 

Wiarton A 214 C 240 D 264 P 124 S 134 

Williamsburg A 214 C 240 D 264 

P 124 S 135 
Winchester 55, A 214 C 240 D 264 

P 124 S 135 
Windermere A 214 C 240 D 264 

P 124 S 135 

Wind gauge 19, 84 

Windsor 50, A 214 C 240 D 264 

P 124 S 135 
Wingham . . .A 215 C 240 D 264 P 124 S 135 



Index 



279 



Winnipeg River 15 

Woodbridge A 215 C 240 D 264 

P 124 S 135 
Woodstock 50, A 215 C 240 D 264 

P 124 S 135 
Woodville. . .A 215 C 240 D 264 P 124 S 135 

Work week, reduction in 88 

Wyoming . . A 215 C 240 D 264 P 124 S 135 



York Twp 67, A 215 C 240 D 264 

P 124 S 135 
Young, H. G., Mines Limited 162 



7. 



Zurich A 215 C 240 D 264 P 124 S 135 



Code ietters .4, C, D, with page references, represent each of the statementsjso designated. P represents Cost 
of Primary Power, and 5 Sinking Fund Equity. 



p. 



APRir 



Gov. Doc. Ontario. Hydro-Electric 
Ont Power Commissioa. 
H Annual report 

▼• 53-54(1960-61) 



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